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Home My WebLink About197-0741. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Changeout 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8,895'N/A Casing Collapse Conductor 470psi Surface 3,090psi Production 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Operations Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 Perforation Depth MD (ft): See Schematic See Schematic 4-1/2" 4.5"x7" Premier Prod & 2-3/8" Baker LTP and N/A 8,154 MD/ 6,718 TVD & 8,316 MD/ 6,880 TVD and N/A 5,570' 8,880' 112' 20" 9-5/8" 7" 5,570' 8,880' 12.6# / L-80 / TXP TVD Burst 8,316' MD 1,490psi 5,750psi 7,240psi 4,576' 7,444' C.O. 816 Length Size Proposed Pools: 112' 112' 8/16/2025 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509 & ADL0388235 197-074 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22762-00-00 Hilcorp Alaska LLC Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 7,459' 8,797' 7,361' 1,201' N/A Subsequent Form Required: Suspension Expiration Date: Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 2-7/8" 6.5# / L-80 / EUE 8rd 8,123' MILNE PT UNIT F-05 MILNE POINT KUPARUK RIVER OIL N/A Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 10:24 am, Aug 01, 2025 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.08.01 09:45:16 - 08'00' Taylor Wellman (2143) 325-456 10-404 * BOPE test to 2000 psi. * Approved to run ~ 625' feet of TCP guns on ASR rig. SFD 8/11/2025 DSR-8/14/25MGR07AUG25JLC 8/14/2025 8/14/2025Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.08.14 11:57:58 -08'00' RBDMS JSB 081825 Well: MPF-05 PTD: 197-074 API: 50-029-22762-00-00 Well Name:MPF-05 API Number:50-029-22762-00-00 Current Status:Shut-in ESP Rig:ASR #1 Estimated Start Date:8/16/2024 Estimated Duration:5days Regulatory Contact:Tom Fouts Permit to Drill Number:197-074 First Call Engineer:Ryan Lewis (303) 906-5178 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 1861 psi @ 6,603’ TVD 7/1/2025 | 5.6 EMW, 5.8 KWF Max Potential Surface Pressure: 1,201 psi Gas Column Gradient (0.1 psi/ft) Max Angle: 61° Sail Angle from 5,250’ MD Brief Well Summary: Well F-05 was drilled by Nabors 22E, perforated/fractured and completed by Nabors 4ES in May 1997 as a Kuparuk A2-sand producer. RWO’s to replace the ESP in 7/97, 4/00, 12/00 & 2/01 due to frac sand. During the ESP replacement in June 2001, 250-micron screens were installed to prevent frac sand production. This ESP ran until early May 2005 when it shut down due to an electrical failure. During the RWO in late May 2005 the screens were pulled and the A1 & A3 sands were perforated. The ESP was replaced in June 2012. This ESP failed in November 2015 and was SI. In March 2021 the ESP was pulled and a 4-1/2” JP Completion was installed. April 2021 MP F-05 was CTD sidetracked into a new Kuparuk Fault block. MP F-05 Jet completion ran until a hole in the TBG developed and the well was SI on 11-25-2021. The well has been an ESP 2022-25. The ESP failed electrically. Objectives: Pull failed ESP completion, cleanout run, add perfs and run new ESP completion. Notes Regarding Wellbore Condition: - 7” casing test to 3,500 psi on 3/14/2021. 8-year casing test not required. Pre-Rig Procedure (Non Sundried Work) Pumping & Well Support 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 barrel returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 barrel returns tank. Bullhead down tbg and IA taking returns to formation as needed to establish and maintain a full column of produced water. 6. Confirm well is dead. Contact operations engineer if freeze protection is needed prior to ASR arrival. 7. RD Little Red Services and reverse out skid. 8. Set BPV. ND tree. NU BOPE. Brief RWO Procedure (Begin Sundried Work) Well: MPF-05 PTD: 197-074 API: 50-029-22762-00-00 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 barrel returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. a. If needed, kill well with produced water prior to setting CTS. 3. Test BOPE to 250 psi low/ 2,000 psi high. Test annular to 250 psi low/ 2,000 psi high (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test 1.66” (tube OD for 1-1/4” CS Hydril) single pipe ram. e. Test VBR rams on 2-7/8” and 3-1/2” test joint. f. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Bleed any pressure on casing to the returns tank. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with produced water as needed. Pull BPV. a. If indications show pressure underneath BPV, lubricate out BPV. 5. Call out Summit for ESP pull. Yes, Summit will pull the Baker equipment. We are not bringing out Baker for the pull and summit for the install. 6. RU spoolers to handle ESP cable. 7. MU landing joint or spear, BOLDS, PU on the tubing hanger. a. Tubing hanger is an -1/2” TC-1A-EMS 11 x 4-1/2” Atlas Bradford TC-II, 12.6# top & bottom b. 2021 tubing PU weight on ASR #1 recorded as 91kip. Slack off weight recorded as 76 kip. c. 2-7/8” L-80 EUE yield is 144 kip. 8. Confirm hanger free, lay down tubing hanger. 9. POOH and lay down the 2-7/8” tubing. a. Re-use all tubing. b. Keep ported discharge head and centralizer for future use. c. Note any sand or scale inside or on the outside of the ESP on the morning report. d. Recorded Clamp Totals: i. Canon Clamps: 132 ii. Protectolizers: 5 10. Lay Down ESP. 11. RIH with down jet nozzle, +-1,385’ of 1.25” PH8 and 3-1/2” workstring to 8,550’ MD. 12. Stop and break circulation from 8,550’ MD. Wash down to 9,330’ MD. Fluff and stuff because you will not have circulation. 13. TOOH. 14. Make up 1-9/16” x 2-7/8” EUE crossover, TIW, safety joint, crossover back to 1-9/16”, ported sub to circulate through, and a solid sub to isolate from the 1-9/16” guns. This will remain on the catwalk while we are on 1-9/16” guns. 15. Arm and RIH with ±625’ of 1-9/16” TCP guns, 800’ 1-1/4” CS Hydrill PH8 and 3-1/2” workstring. 16. TIH, tie-in off pipe tally and perforating the following interval: ±8655 – 9280-ft MD 17. Maintain tubing fill while TIH. 18. Confirm well is dead after perforating. Bullhead 8.6 #/gal KWF as needed. perforating the following interval: ±8655 – 9280-ft MD Well: MPF-05 PTD: 197-074 API: 50-029-22762-00-00 19. TOOH w/ and lay down TCP guns 20. RIH with used 2-7/8” 6.5# L-80 ESP completion to +/- 8,125’ and obtain string weights. a. Check electrical continuity every 1000’. b. Note PU and SO weights on tally. c. Install ESP clamps per Baker, and cross coupling clamps every other joint Nom. Size Length Item Lb/ft Material Notes 5.85 2 Centralizer 4 4.5 2 Intake Sensor 30 5.62 34 Motor - 150HP 80 5.2 7 Lower Tandem Seal 38 5.2 7 Upper Tandem Seal 38 5.2 8 Gas Separator 52 4 21 Pumps – SNFPSH 45 4 21 Pumps – SF1750 45 4 21 Pumps – SF1750 45 1 Ported Discharge Head 13 L-80 2-7/8" 10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 30 2-7/8" EUE 8rd L-80 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"2 XN-nipple 2.313" / 2.205" No-Go 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 60 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" +-7,700 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, 1/4" OV 6.5 L-80 ~200 MD 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 150 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8" 10 Space out pup 6.5 L-80 2-7/8" 30 Tubing Hanger with full joint 6.5 L-80 21. Land tubing hanger. Use extra caution to not damage cable. 22. Lay down landing joint. 23. Set BPV. 24. RDMO ASR. Post-Rig Procedure: Well Support Well: MPF-05 PTD: 197-074 API: 50-029-22762-00-00 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE, set CTS plug, and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull CTS and BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. RU well house and flowlines. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Triple BOPE Schematic _____________________________________________________________________________________ Revised By: RJL 6/27/2025 SCHEMATIC Milne Point Unit Well: MP F-05 / L1 / L1-01 Last Completed: 3/5/2022 PTD: 197-074 / 221-014 / 221-015 2-3/8” XO Slotted to Solid Liner @ 9,584’ (F-05L1-01) Whipstock (L1) set in 3-1/4” @9,430’ TD =8,895’ (MD) / TD = 7,459’(TVD) 20” Top of Whipstock @ 8,365’ Orig. KB Elev.: 41.3’/ GL Elev.: 12.3’ 7” 10 & 11 8 3 6 & 7 14 15 16 9 13 12 9-5/8” ES Cementer @ 2,005 MD 9-5/8” 1 2 Top of 4-1/2” Tubing cut @ 8,145’ 12-4-2021 KUP A3 Sands Top of 3-1/4” Liner @ 8,310’ Liner top Packer @8,316’ PBTD =8,797’(MD) / PBTD = 7,361’(TVD) 4 & 5 Top of 2-3/8” Liner @ 8,318’17 KUP A2 Sands KUP A1 Sands Two 7” x 21’ Marker Joints f/ 8,273’ – 8,314’ RKB 8 & 9 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 9-5/8" Surface 40 / L-80 / Btrc. 8.679 Surface 5,570’ 7" Production 26 / L-80 / Btc Mod 6.276 Surface 8,880’ L1: 3-1/4” Solid Liner 6.6 / L-80 / TCII 8,310’ 9,690’ L1-01: 2-3/8” Solid/Slotted Liner 4.7 / L-80 / STL & H511 8,318’ 11,210’ TUBING DETAIL 2-7/8” Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 8,123’ 4-1/2" Tubing 12.6 / L-80 / TXP 3.958” 8,145’ 8,316’ WELL INCLINATION DETAIL KOP @ 2,000’ Max Hole Angle = 61 deg. @ 5,220’ F-05L1 window @ 8,374’, F-05L1-01 window @ 9,378’ TREE & WELLHEAD Tree Cameron 4-1/16” 5M Wellhead 11” x 11” 5K FMC Gen 5A, w/ 4-1/2” Atlas Bradford hgr. Tbg Hanger 4-1/2” TC-1A-EMS 11 x 4-1/2” Atlas Bradford TC-II, 12.6# top & bottom GENERAL WELL INFO API: 50-029-22762-00-00 / 60-00 / 61-00 Drilled and Cased by Nabors 22E - 5/7/1997 1st Perforated w/ Wireline –5/18/1997 RWO Tubing Swap: 3/12/2021 L1 & L1-01 Sidetrack: 5/21/2021 JEWELRY DETAIL No Depth Item 1 198’ Sta. 2: 2-7/8" GLM W/ dual port OV 2 7,939’ Sta. 1: 2-7/8" GLM W/ 1" Dummy Valve 3 7,996’ 2-7/8” XN Nipple –ID= 2.205” No-Go 4 8,047’ Discharge Head: B/O PMP 513 2-7/8 X 8 EUE 5 8,048’ Zenith Ported Sub: PRESS PORT 513/538P PMP 6 8,043’ Pump #2: 538PMSXD FLEX27 82 FER H6 STD_PNT 7 8,066’ Pump #1: 538PMSXD 068 G31 M FER NO_PNT 8 8,082’ Gas Separator: 538GSTHVEVX MT H6 FER STD PNT 9 8,087’ Bolt on Intake: GPXARCINT FER H6 10 8,088’ Upper Tandem Seal: GSB3DB H6 SB/AB PFSA 11 8,095’ Lower Tandem Seal: GSB3DB H6 SB/AB PFSA 12 8,102’ Motor: 562XP 250 Hp/2,505 V/61 A 13 8,118’ Sensor Gauge w/ Centralizer –Btm @ 8,123’ 14 8,154’ 4-1/2” x 7” Baker Premier Production Packer 15 8,225’ X Nipple, ID = 3.813” 16 8,276’ WELG, bottom at 8,316’**SEE NOTE** 17 8,316’ 2-3/8” Baker Liner Top Packer Bottom of 3-1/4” Protection String @ 9,690’ Packer Whipstock (L1- 01) set in 3-1/4” NOTE: Per CTD GR/CCL Tie-In log, Tubing tail 38’ deeper @ 8,354’ MDF-05L1-01 TD = 11,210’ (MD) / 7,157’ (TVD) PB TD = 11,210’ (MD) / 7,157’ (TVD) F-05L1 TD = 10,817’ (MD) / 7,189’ (TVD) PBTD = 10,817’ (MD) / 7,189’ (TVD) PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status F-05: Kup A3 8,460’ 8,472’ 7,024’ 7,036’ 12 5/31/2005 Closed F-05: Kup. A2 8,478’ 8,498’ 7,042’ 7,062’ 20 5/18/1997 Closed F-05: Kup. A1 8,503’ 8,523’ 7,067’ 7,087’ 20 5/31/2005 Closed F-05L1: Kup A 9,429’ 10,817’ 7,103’ 7,189’ 1,388 5/14/2021 Closed F-05L1-01: Kup A 9,584’ 11,209’ 7,146’ 7,157’ 1,625 5/19/2021 Open OPEN HOLE / CEMENT DETAIL 24" Cmt w/ 250 sks of Arcticset I (Approx.) 12-1/4" Cmt w/ 1,436 sks PF ‘E’, 600 sx Class ‘G’ 8-1/2” Cmt w/ 250 sks Class ‘G’ 4-1/4” x 3” Uncemented Solid / Slotted Liner (MPU F-05L1 & L1-01) _____________________________________________________________________________________ Revised By: TDF 6/30/2025 PROPOSED Milne Point Unit Well: MP F-05 / L1 / L1-01 Last Completed: 3/5/2022 PTD: 197-074 / 221-014 / 221-015 2-3/8” XO Slotted to Solid Liner @ 9,584’ (F-05L1-01) Whipstock (L1) set in 3-1/4” @9,430’ TD =8,895’ (MD) / TD = 7,459’(TVD) 20” Top of Whipstock @ 8,365’ Orig. KB Elev.: 41.3’/ GL Elev.: 12.3’ 7” 10 & 11 8 3 6 & 7 14 15 16 9 13 12 9-5/8” ES Cementer @ 2,005 MD 9-5/8” 1 2 Top of 4-1/2” Tubing cut @ 8,145’ 12-4-2021 KUP A3 Sands Top of 3-1/4” Liner @ 8,310’ Liner top Packer @8,316’ PBTD =8,797’(MD) / PBTD = 7,361’(TVD) 4 & 5 Top of 2-3/8” Liner @ 8,318’17 KUP A2 Sands KUP A1 Sands Two 7” x 21’ Marker Joints f/ 8,273’ – 8,314’ RKB 8 & 9 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 9-5/8" Surface 40 / L-80 / Btrc. 8.679 Surface 5,570’ 7" Production 26 / L-80 / Btc Mod 6.276 Surface 8,880’ L1: 3-1/4” Solid Liner 6.6 / L-80 / TCII 8,310’ 9,690’ L1-01: 2-3/8” Solid/Slotted Liner 4.7 / L-80 / STL & H511 8,318’ 11,210’ TUBING DETAIL 2-7/8” Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface ±X,XXX’ 4-1/2" Tubing 12.6 / L-80 / TXP 3.958” 8,145’ 8,316’ WELL INCLINATION DETAIL KOP @ 2,000’ Max Hole Angle = 61 deg. @ 5,220’ F-05L1 window @ 8,374’, F-05L1-01 window @ 9,378’ TREE & WELLHEAD Tree Cameron 4-1/16” 5M Wellhead 11” x 11” 5K FMC Gen 5A, w/ 4-1/2” Atlas Bradford hgr. Tbg Hanger 4-1/2” TC-1A-EMS 11 x 4-1/2” Atlas Bradford TC-II, 12.6# top & bottom GENERAL WELL INFO API: 50-029-22762-00-00 / 60-00 / 61-00 Drilled and Cased by Nabors 22E - 5/7/1997 1st Perforated w/ Wireline –5/18/1997 RWO Tubing Swap: 3/12/2021 L1 & L1-01 Sidetrack: 5/21/2021 JEWELRY DETAIL No Depth Item 1 ±XXX’ Sta. 2: 2-7/8" GLM 2 ±X,XXX’ Sta. 1: 2-7/8" GLM 3 ±X,XXX’ 2-7/8” XN Nipple –ID= 2.205” No-Go 4 ±X,XXX’ Discharge Head: 5 ±X,XXX’ Zenith Ported Sub: 6 ±X,XXX’ Pump #2: 7 ±X,XXX’ Pump #1: 8 ±X,XXX’ Gas Separator: 9 ±X,XXX’ Bolt on Intake: 10 ±X,XXX’ Upper Tandem Seal: 11 ±X,XXX’ Lower Tandem Seal: 12 ±X,XXX’ Motor: 13 ±X,XXX’ Sensor Gauge w/ Centralizer –Btm @ 8,123’ 14 8,154’ 4-1/2” x 7” Baker Premier Production Packer 15 8,225’ X Nipple, ID = 3.813” 16 8,276’ WELG, bottom at 8,316’**SEE NOTE** 17 8,316’ 2-3/8” Baker Liner Top Packer Bottom of 3-1/4” Protection String @ 9,690’ Packer Whipstock (L1- 01) set in 3-1/4” NOTE: Per CTD GR/CCL Tie-In log, Tubing tail 38’ deeper @ 8,354’ MDF-05L1-01 TD = 11,210’ (MD) / 7,157’ (TVD) PB TD = 11,210’ (MD) / 7,157’ (TVD) F-05L1 TD = 10,817’ (MD) / 7,189’ (TVD) PBTD = 10,817’ (MD) / 7,189’ (TVD) PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status F-05: Kup A3 8,460’ 8,472’ 7,024’ 7,036’ 12 5/31/2005 Closed F-05: Kup. A2 8,478’ 8,498’ 7,042’ 7,062’ 20 5/18/1997 Closed F-05: Kup. A1 8,503’ 8,523’ 7,067’ 7,087’ 20 5/31/2005 Closed F-05: Kup. A1 ±8,655’ ±9,280’ ±7,219’ ±7,098’ ±625 Future Future F-05L1: Kup A 9,429’ 10,817’ 7,103’ 7,189’ 1,388 5/14/2021 Closed F-05L1-01: Kup A 9,584’ 11,209’ 7,146’ 7,157’ 1,625 5/19/2021 Open OPEN HOLE / CEMENT DETAIL 24" Cmt w/ 250 sks of Arcticset I (Approx.) 12-1/4" Cmt w/ 1,436 sks PF ‘E’, 600 sx Class ‘G’ 8-1/2” Cmt w/ 250 sks Class ‘G’ 4-1/4” x 3” Uncemented Solid / Slotted Liner (MPU F-05L1 & L1-01) Updated 2/20/2024 11” BOPE INTEGRATED 11'’-5000 INTEGRATED 4.30'INTEGRATED 11" - 5000 2-7/8" x 5" VBR Blind 11'’- 5000 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManual Stripping Head ManualManual 1.66" Pipe Ram Milne Point ASR 11” BOP w/ Jacks 05/17/2017 Milne Point ASR 11” BOP (Triple) 7/28/2025 Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 7/23/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250723 Well API #PTD #Log Date Log Company AOGCC ESet # END 1-25A 50029217220100 197075 6/19/2025 HALLIBURTON T40691 KU 41-08 50133207170000 224005 6/30/2025 AK E-LINE T40692 MPU F-05 50029227620000 197074 7/1/2025 READ T40693 MPU J-02 50029220710000 190096 5/21/2025 YELLOWJACKET T40694 MPU R-106 50029238160000 225033 6/8/2025 HALLIBURTON T40695 MPU R-107 50029238190000 225049 7/11/2025 YELLOWJACKET T40696 ODSK-41 50703205850000 208147 6/13/2025 HALLIBURTON T40697 ODSN-02 50703206710000 213046 6/13/2025 HALLIBURTON T40698 ODSN-16 50703206200000 210053 6/14/2025 HALLIBURTON T40699 ODSN-17 50703206220000 210093 6/14/2025 HALLIBURTON T40700 ODSN-24 50703206620000 212178 6/15/2025 HALLIBURTON T40701 ODSN-28 50703206760000 213148 6/17/2025 HALLIBURTON T40702 ODSN-36 50703205610000 207182 6/12/2025 HALLIBURTON T40703 PBU 07-23C 50029216350300 225043 7/4/2025 HALLIBURTON T40704 PBU 14-18C 50029205510300 225040 6/25/2025 HALLIBURTON T40705 PBU 15-33C 50029224480300 216075 7/3/2025 HALLIBURTON T40706 PBU C-30A 50029217770100 208169 7/1/2025 HALLIBURTON T40707 PBU E-09C 50029204660300 209095 6/30/2025 HALLIBURTON T40708 PBU F-38B 50029220930300 225029 6/12/2025 HALLIBURTON T40709 PBU GNI-02A 50029228510100 206119 7/4/2025 HALLIBURTON T40710 PBU GNI-02A 50029228510100 206119 7/3/2025 HALLIBURTON T40710 PBU GNI-04 50029233670000 207117 6/27/2025 HALLIBURTON T40711 PBU GNI-04 50029233670000 207117 6/27/2025 HALLIBURTON T40711 PBU J-07C 50029202410300 225026 5/30/2025 HALLIBURTON T40712 PBU L-105 50029230750000 202058 6/24/2025 YELLOWJACKET T40713 PBU L-108 50029230900000 202109 6/23/2025 YELLOWJACKET T40714 PBU NK-25 50029227600000 197068 6/5/2025 YELLOWJACKET T40715 PBU P2-06 50029223880000 193103 6/19/2025 HALLIBURTON T40716 PBU S-104 50029229880000 200196 6/21/2025 YELLOWJACKET T40717 T40693MPU F-05 50029227620000 197074 7/1/2025 READ Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.28 09:54:00 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: PCU-05 50283202030000 225037 7/3/2025 YELLOWJACKET T40718 TBU D-08RD 50733201070100 174003 6/4/2025 READ T40719 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.28 09:53:40 -08'00' 1 Christianson, Grace K (OGC) From:Rixse, Melvin G (OGC) Sent:Tuesday, July 22, 2025 3:16 PM To:Christianson, Grace K (OGC) Subject:Reject - PTD 197-074 MPU F-05 Sundry Request 325-422 Follow Up Flag:Follow up Flag Status:Completed Grace, I sent this email to Hilcorp. Mel From: Rixse, Melvin G (OGC) Sent: Tuesday, July 22, 2025 3:13 PM To: Ryan Lewis <ryan.lewis@hilcorp.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: PTD 197-074 MPU F-05 Sundry Request 325-422 Ryan, This sundry is rejected because the BOPE does not meet the following regulation: 20 AAC 25.285. Secondary well control for tubing workover operations: blowout prevention equipment requirements (c) Well control equipment must include (1) at least one positive seal manual or hydraulic valve or BOPE blind ram and one set of BOPE pipe rams Ʋanged to the wellhead; (2) in rotary drilling rig operations, (A) for an operation with a maximum potential surface pressure of 3,000 psi or less, at least three preventers, including (i) one equipped with pipe rams that Ʊt the size of drill pipe, tubing, liner or casing being used, except that pipe rams need not be sized to bottom-hole assemblies (BHAs) and drill collars; 1,385’ of 1-1/4” PH8 work string will require pipe rams. AOGCC will consider 500’ (or less) of jointed pipe without properly sized rams as BHA. 1385’ is considered a tapered work string. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 OƯice 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). 2 cc. Dewhurst, Davies, Roby, Lau RBDMS JSB 072425 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Changeout 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8,895'N/A Casing Collapse Conductor 470psi Surface 3,090psi Production 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Operations Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 Perforation Depth MD (ft): See Schematic See Schematic 4-1/2" 4.5"x7" Premier Prod & 2-3/8" Baker LTP and N/A 8,154 MD/ 6,718 TVD & 8,316 MD/ 6,880 TVD and N/A 5,570' 8,880' 112' 20" 9-5/8" 7" 5,570' 8,880' 12.6# / L-80 / TXP TVD Burst 8,316' MD 1,490psi 5,750psi 7,240psi 4,576' 7,444' C.O. 816 Length Size Proposed Pools: 112' 112' 8/1/2025 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509 & ADL0388235 197-074 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22762-00-00 Hilcorp Alaska LLC Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 7,459' 8,797' 7,361' 1,201' N/A Subsequent Form Required: Suspension Expiration Date: Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 2-7/8" 6.5# / L-80 / EUE 8rd 8,123' MILNE PT UNIT F-05 MILNE POINT KUPARUK RIVER OIL N/A Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-422 By Gavin Gluyas at 10:25 am, Jul 16, 2025 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.07.16 09:17:30 - 08'00' Taylor Wellman (2143) DSR-7/16/25 NOT APPROVED 7/22/25 MGR Well: MPF-05 PTD: 197-074 API: 50-029-22762-00-00 Well Name:MPF-05 API Number:50-029-22762-00-00 Current Status:Shut-in ESP Rig:ASR #1 Estimated Start Date:8/1/2024 Estimated Duration:5days Regulatory Contact:Tom Fouts Permit to Drill Number:197-074 First Call Engineer:Ryan Lewis (303) 906-5178 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 1861 psi @ 6,603’ TVD 7/1/2025 | 5.6 EMW, 5.8 KWF Max Potential Surface Pressure: 1,201 psi Gas Column Gradient (0.1 psi/ft) Max Angle: 61° Sail Angle from 5,250’ MD Brief Well Summary: Well F-05 was drilled by Nabors 22E, perforated/fractured and completed by Nabors 4ES in May 1997 as a Kuparuk A2-sand producer. RWO’s to replace the ESP in 7/97, 4/00, 12/00 & 2/01 due to frac sand. During the ESP replacement in June 2001, 250-micron screens were installed to prevent frac sand production. This ESP ran until early May 2005 when it shut down due to an electrical failure. During the RWO in late May 2005 the screens were pulled and the A1 & A3 sands were perforated. The ESP was replaced in June 2012. This ESP failed in November 2015 and was SI. In March 2021 the ESP was pulled and a 4-1/2” JP Completion was installed. April 2021 MP F-05 was CTD sidetracked into a new Kuparuk Fault block. MP F-05 Jet completion ran until a hole in the TBG developed and the well was SI on 11-25-2021. The well has been an ESP 2022-25. The ESP failed electrically. Objectives: Pull failed ESP completion, cleanout run, add perfs and run new ESP completion. Notes Regarding Wellbore Condition: - 7” casing test to 3,500 psi on 3/14/2021. 8-year casing test not required. Pre-Rig Procedure (Non Sundried Work) Pumping & Well Support 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 barrel returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 barrel returns tank. Bullhead down tbg and IA taking returns to formation as needed to establish and maintain a full column of produced water. 6. Confirm well is dead. Contact operations engineer if freeze protection is needed prior to ASR arrival. 7. RD Little Red Services and reverse out skid. 8. Set BPV. ND tree. NU BOPE. Brief RWO Procedure (Begin Sundried Work) Well: MPF-05 PTD: 197-074 API: 50-029-22762-00-00 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 barrel returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. a. If needed, kill well with produced water prior to setting CTS. 3. Test BOPE to 250 psi low/ 2,000 psi high. Test annular to 250 psi low/ 2,000 psi high (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test VBR rams on 2-7/8” and 3-1/2” test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Bleed any pressure on casing to the returns tank. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with produced water as needed. Pull BPV. a. If indications show pressure underneath BPV, lubricate out BPV. 5. Call out Summit for ESP pull. Yes, Summit will pull the Baker equipment. We are not bringing out Baker for the pull and summit for the install. 6. RU spoolers to handle ESP cable. 7. MU landing joint or spear, BOLDS, PU on the tubing hanger. a. Tubing hanger is an -1/2” TC-1A-EMS 11 x 4-1/2” Atlas Bradford TC-II, 12.6# top & bottom b. 2021 tubing PU weight on ASR #1 recorded as 91kip. Slack off weight recorded as 76 kip. c. 2-7/8” L-80 EUE yield is 144 kip. 8. Confirm hanger free, lay down tubing hanger. 9. POOH and lay down the 2-7/8” tubing. a. Re-use all tubing. b. Keep ported discharge head and centralizer for future use. c. Note any sand or scale inside or on the outside of the ESP on the morning report. d. Recorded Clamp Totals: i. Canon Clamps: 132 ii. Protectolizers: 5 10. Lay Down ESP. 11. Make up 1-1/4” PH8 x 2-7/8” EUE crossover, TIW, safety joint, crossover back to 1-1/4” PH8. This will remain on the catwalk while we are on 1-1/4” tubing. 12. RIH with down jet nozzle, +-1,385’ of 1.25” PH8 and 3-1/2” workstring to 8,550’ MD. 13. Stop and break circulation from 8,550’ MD. Wash down to 9,330’ MD. Fluff and stuff because you will not have circulation. 14. TOOH. 15. Make up 1-9/16” x 2-7/8” EUE crossover, TIW, safety joint, crossover back to 1-9/16”, ported sub to circulate through, and a solid sub to isolate from the 1-9/16” guns. This will remain on the catwalk while we are on 1-9/16” guns. 16. Arm and RIH with ±625’ of 1-9/16” TCP guns 17. TIH and perforating the following interval: 18. ±8655 – 9280-ft MD Well: MPF-05 PTD: 197-074 API: 50-029-22762-00-00 19. Maintain tubing fill while TIH 20. Confirm well is dead after perforating. Bullhead 8.6 #/gal KWF as needed. 21. TOOH w/ and lay down TCP guns 22. RIH with used 2-7/8” 6.5# L-80 ESP completion to +/- 8,125’ and obtain string weights. a. Check electrical continuity every 1000’. b. Note PU and SO weights on tally. c. Install ESP clamps per Baker, and cross coupling clamps every other joint Nom. Size Length Item Lb/ft Material Notes 5.85 2 Centralizer 4 4.5 2 Intake Sensor 30 5.62 34 Motor - 150HP 80 5.2 7 Lower Tandem Seal 38 5.2 7 Upper Tandem Seal 38 5.2 8 Gas Separator 52 4 21 Pumps – SNFPSH 45 4 21 Pumps – SF1750 45 4 21 Pumps – SF1750 45 1 Ported Discharge Head 13 L-80 2-7/8" 10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 30 2-7/8" EUE 8rd L-80 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"2 XN-nipple 2.313" / 2.205" No-Go 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 60 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" +-7,700 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, 1/4" OV 6.5 L-80 ~200 MD 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 150 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8" 10 Space out pup 6.5 L-80 2-7/8" 30 Tubing Hanger with full joint 6.5 L-80 23. Land tubing hanger. Use extra caution to not damage cable. 24. Lay down landing joint. 25. Set BPV. 26. RDMO ASR. Well: MPF-05 PTD: 197-074 API: 50-029-22762-00-00 Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE, set CTS plug, and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull CTS and BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. RU well house and flowlines. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Double BOPE Schematic _____________________________________________________________________________________ Revised By: RJL 6/27/2025 SCHEMATIC Milne Point Unit Well: MP F-05 / L1 / L1-01 Last Completed: 3/5/2022 PTD: 197-074 / 221-014 / 221-015 2-3/8” XO Slotted to Solid Liner @ 9,584’ (F-05L1-01) Whipstock (L1) set in 3-1/4” @9,430’ TD =8,895’ (MD) / TD = 7,459’(TVD) 20” Top of Whipstock @ 8,365’ Orig. KB Elev.: 41.3’/ GL Elev.: 12.3’ 7” 10 & 11 8 3 6 & 7 14 15 16 9 13 12 9-5/8” ES Cementer @ 2,005 MD 9-5/8” 1 2 Top of 4-1/2” Tubing cut @ 8,145’ 12-4-2021 KUP A3 Sands Top of 3-1/4” Liner @ 8,310’ Liner top Packer @8,316’ PBTD =8,797’(MD) / PBTD = 7,361’(TVD) 4 & 5 Top of 2-3/8” Liner @ 8,318’17 KUP A2 Sands KUP A1 Sands Two 7” x 21’ Marker Joints f/ 8,273’ – 8,314’ RKB 8 & 9 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 9-5/8" Surface 40 / L-80 / Btrc. 8.679 Surface 5,570’ 7" Production 26 / L-80 / Btc Mod 6.276 Surface 8,880’ L1: 3-1/4” Solid Liner 6.6 / L-80 / TCII 8,310’ 9,690’ L1-01: 2-3/8” Solid/Slotted Liner 4.7 / L-80 / STL & H511 8,318’ 11,210’ TUBING DETAIL 2-7/8” Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 8,123’ 4-1/2" Tubing 12.6 / L-80 / TXP 3.958” 8,145’ 8,316’ WELL INCLINATION DETAIL KOP @ 2,000’ Max Hole Angle = 61 deg. @ 5,220’ F-05L1 window @ 8,374’, F-05L1-01 window @ 9,378’ TREE & WELLHEAD Tree Cameron 4-1/16” 5M Wellhead 11” x 11” 5K FMC Gen 5A, w/ 4-1/2” Atlas Bradford hgr. Tbg Hanger 4-1/2” TC-1A-EMS 11 x 4-1/2” Atlas Bradford TC-II, 12.6# top & bottom GENERAL WELL INFO API: 50-029-22762-00-00 / 60-00 / 61-00 Drilled and Cased by Nabors 22E - 5/7/1997 1st Perforated w/ Wireline –5/18/1997 RWO Tubing Swap: 3/12/2021 L1 & L1-01 Sidetrack: 5/21/2021 JEWELRY DETAIL No Depth Item 1 198’ Sta. 2: 2-7/8" GLM W/ dual port OV 2 7,939’ Sta. 1: 2-7/8" GLM W/ 1" Dummy Valve 3 7,996’ 2-7/8” XN Nipple –ID= 2.205” No-Go 4 8,047’ Discharge Head: B/O PMP 513 2-7/8 X 8 EUE 5 8,048’ Zenith Ported Sub: PRESS PORT 513/538P PMP 6 8,043’ Pump #2: 538PMSXD FLEX27 82 FER H6 STD_PNT 7 8,066’ Pump #1: 538PMSXD 068 G31 M FER NO_PNT 8 8,082’ Gas Separator: 538GSTHVEVX MT H6 FER STD PNT 9 8,087’ Bolt on Intake: GPXARCINT FER H6 10 8,088’ Upper Tandem Seal: GSB3DB H6 SB/AB PFSA 11 8,095’ Lower Tandem Seal: GSB3DB H6 SB/AB PFSA 12 8,102’ Motor: 562XP 250 Hp/2,505 V/61 A 13 8,118’ Sensor Gauge w/ Centralizer –Btm @ 8,123’ 14 8,154’ 4-1/2” x 7” Baker Premier Production Packer 15 8,225’ X Nipple, ID = 3.813” 16 8,276’ WELG, bottom at 8,316’**SEE NOTE** 17 8,316’ 2-3/8” Baker Liner Top Packer Bottom of 3-1/4” Protection String @ 9,690’ Packer Whipstock (L1- 01) set in 3-1/4” NOTE: Per CTD GR/CCL Tie-In log, Tubing tail 38’ deeper @ 8,354’ MDF-05L1-01 TD = 11,210’ (MD) / 7,157’ (TVD) PB TD = 11,210’ (MD) / 7,157’ (TVD) F-05L1 TD = 10,817’ (MD) / 7,189’ (TVD) PBTD = 10,817’ (MD) / 7,189’ (TVD) PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status F-05: Kup A3 8,460’ 8,472’ 7,024’ 7,036’ 12 5/31/2005 Closed F-05: Kup. A2 8,478’ 8,498’ 7,042’ 7,062’ 20 5/18/1997 Closed F-05: Kup. A1 8,503’ 8,523’ 7,067’ 7,087’ 20 5/31/2005 Closed F-05L1: Kup A 9,429’ 10,817’ 7,103’ 7,189’ 1,388 5/14/2021 Closed F-05L1-01: Kup A 9,584’ 11,209’ 7,146’ 7,157’ 1,625 5/19/2021 Open OPEN HOLE / CEMENT DETAIL 24" Cmt w/ 250 sks of Arcticset I (Approx.) 12-1/4" Cmt w/ 1,436 sks PF ‘E’, 600 sx Class ‘G’ 8-1/2” Cmt w/ 250 sks Class ‘G’ 4-1/4” x 3” Uncemented Solid / Slotted Liner (MPU F-05L1 & L1-01) _____________________________________________________________________________________ Revised By: TDF 6/30/2025 PROPOSED Milne Point Unit Well: MP F-05 / L1 / L1-01 Last Completed: 3/5/2022 PTD: 197-074 / 221-014 / 221-015 Whipstock (L1) set in 3-1/4” @9,430’ TD =8,895’ (MD) / TD = 7,459’(TVD) 20” Top of Whipstock @ 8,365’ Orig. KB Elev.: 41.3’/ GL Elev.: 12.3’ 7” 10 & 11 8 3 6 & 7 14 15 16 9 13 12 9-5/8” ES Cementer @ 2,005 MD 9-5/8” 1 2 Top of 4-1/2” Tubing cut @ 8,145’ 12-4-2021 KUP A3 Sands Top of 3-1/4” Liner @ 8,310’ Liner top Packer @8,316’ PBTD =8,797’(MD) / PBTD = 7,361’(TVD) 4 & 5 Top of 2-3/8” Liner @ 8,318’17 KUP A2 Sands KUP A1 Sands Two 7” x 21’ Marker Joints f/ 8,273’ – 8,314’ RKB 8 & 9 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 9-5/8" Surface 40 / L-80 / Btrc. 8.679 Surface 5,570’ 7" Production 26 / L-80 / Btc Mod 6.276 Surface 8,880’ L1: 3-1/4” Solid Liner 6.6 / L-80 / TCII 8,310’ 9,690’ L1-01: 2-3/8” Solid/Slotted Liner 4.7 / L-80 / STL & H511 8,318’ 11,210’ TUBING DETAIL 2-7/8” Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface ±X,XXX’ 4-1/2" Tubing 12.6 / L-80 / TXP 3.958” 8,145’ 8,316’ WELL INCLINATION DETAIL KOP @ 2,000’ Max Hole Angle = 61 deg. @ 5,220’ F-05L1 window @ 8,374’, F-05L1-01 window @ 9,378’ TREE & WELLHEAD Tree Cameron 4-1/16” 5M Wellhead 11” x 11” 5K FMC Gen 5A, w/ 4-1/2” Atlas Bradford hgr. Tbg Hanger 4-1/2” TC-1A-EMS 11 x 4-1/2” Atlas Bradford TC-II, 12.6# top & bottom GENERAL WELL INFO API: 50-029-22762-00-00 / 60-00 / 61-00 Drilled and Cased by Nabors 22E - 5/7/1997 1st Perforated w/ Wireline –5/18/1997 RWO Tubing Swap: 3/12/2021 L1 & L1-01 Sidetrack: 5/21/2021 JEWELRY DETAIL No Depth Item 1 ±XXX’ Sta. 2: 2-7/8" GLM 2 ±X,XXX’ Sta. 1: 2-7/8" GLM 3 ±X,XXX’ 2-7/8” XN Nipple –ID= 2.205” No-Go 4 ±X,XXX’ Discharge Head: 5 ±X,XXX’ Zenith Ported Sub: 6 ±X,XXX’ Pump #2: 7 ±X,XXX’ Pump #1: 8 ±X,XXX’ Gas Separator: 9 ±X,XXX’ Bolt on Intake: 10 ±X,XXX’ Upper Tandem Seal: 11 ±X,XXX’ Lower Tandem Seal: 12 ±X,XXX’ Motor: 13 ±X,XXX’ Sensor Gauge w/ Centralizer –Btm @ 8,123’ 14 8,154’ 4-1/2” x 7” Baker Premier Production Packer 15 8,225’ X Nipple, ID = 3.813” 16 8,276’ WELG, bottom at 8,316’**SEE NOTE** 17 8,316’ 2-3/8” Baker Liner Top Packer Bottom of 3-1/4” Protection String @ 9,690’ Packer Whipstock (L1- 01) set in 3-1/4” NOTE: Per CTD GR/CCL Tie-In log, Tubing tail 38’ deeper @ 8,354’ MDF-05L1-01 TD = 11,210’ (MD) / 7,157’ (TVD) PB TD = 11,210’ (MD) / 7,157’ (TVD) F-05L1 TD = 10,817’ (MD) / 7,189’ (TVD) PBTD = 10,817’ (MD) / 7,189’ (TVD) PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status F-05: Kup A3 8,460’ 8,472’ 7,024’ 7,036’ 12 5/31/2005 Closed F-05: Kup. A2 8,478’ 8,498’ 7,042’ 7,062’ 20 5/18/1997 Closed F-05: Kup. A1 8,503’ 8,523’ 7,067’ 7,087’ 20 5/31/2005 Closed F-05L1: Kup A 9,429’ 10,817’ 7,103’ 7,189’ 1,388 5/14/2021 Closed F-05L1-01: Kup. A1 ±8,655’ ±9,280’ ±7,219’ ±7,098’ ±625 Future Future F-05L1-01: Kup A 9,584’ 11,209’ 7,146’ 7,157’ 1,625 5/19/2021 Open OPEN HOLE / CEMENT DETAIL 24" Cmt w/ 250 sks of Arcticset I (Approx.) 12-1/4" Cmt w/ 1,436 sks PF ‘E’, 600 sx Class ‘G’ 8-1/2” Cmt w/ 250 sks Class ‘G’ 4-1/4” x 3” Uncemented Solid / Slotted Liner (MPU F-05L1 & L1-01) 2-3/8” XO Slotted to Solid Liner @ 9,584’ (F-05L1-01) Updated 4/7/2025 Milne Point ASR Rig 1 BOPE 2022 11” BOPE 4.48' 4.54' 2.00' CIW-U 4.30'Hydril GK 11" - 5000 VBR or Pipe Rams Blind11'’- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 2-7/8” x 5” VBR STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________MILNE PT UNIT F-05 JBR 03/31/2022 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:6 Test with 2 7/8 and 4 1/2 test joints, tested all Gas Alarms and PVT's, Choke line flanges changed out and passed retest, 4-way on Accumulator Annulus failed, LVBR's failed, HCR Choke failed and Lower Kelly failed. Everything was fixed and retested. I did not witness any of the retest or the Annulus. Closer Times Annulur 13sec, Blinds 7sec, UPR 8sec, LPR 7sec. And both HCR's 3sec., 18 total Precharge Bottles 3ea 1000psi, 4ea 975psi, 7ea 950psi, 1ea 935psi and 3ea 925psi Test Results TEST DATA Rig Rep:T. Shones/A.CarloOperator:Hilcorp Alaska, LLC Operator Rep:D. Yessak/J. Vanderpool Contractor/Rig No.:Doyon 14 PTD#:1970740 DATE:3/3/2022 Type Operation:WRKOV Annular: 250/3500Type Test:INIT Valves: 250/5000 Rams: 250/5000 Test Pressures:Inspection No:bopBDB220304093951 Inspector Brian Bixby Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 27.5 MASP: 2288 Sundry No: 322-057 Location Gen.:P Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Drl. Rig P Hazard Sec.P Misc NA Upper Kelly 1 P Lower Kelly 1 F Ball Type 2 P Inside BOP 2 P FSV Misc 0 NA 14 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 11 13 5/8 NT #1 Rams 1 2 7/8x5 P #2 Rams 1 Blind P #3 Rams 1 2 7/8x5 F #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8 P HCR Valves 2 3 1/8 F Kill Line Valves 2 3 1/8 P Check Valve 0 NA BOP Misc 2 Choke Line Fl FP System Pressure P3000 Pressure After Closure P1650 200 PSI Attained P42 Full Pressure Attained P195 Blind Switch Covers:PYES Nitgn. Bottles (avg):P6@2100 ACC Misc F1 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA 9 9 9 9 99 9 9 9 9 9 $QQXODU 99 9 9 9 9 F NT F F Choke Line Fl FP2 1 F Choke line flanges changed out and passed retest,4-way on Accumulator Annulus failed,LVBR's failed,HCR Choke failed Lower Kelly failed.did not witness any of the retest or the Annulus.AnnulusAnnulus 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ESP Changeout Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8,895 feet N/A feet true vertical 7,459 feet N/A feet Effective Depth measured 8,797 feet 8,154 feet true vertical 7,361 feet 6,718 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 2-7/8" 6.5# / L-80 / EUE 8rd 8,123' 6,687' Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 / TXP 8,316' 6,880' 4.5"x7" Premier Prod 8,154 MD/ 6,718 TVD Packers and SSSV (type, measured and true vertical depth)2-3/8" Baker LTP 8,316 MD/ 6,880 TVD N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Contact Email: Contact Phone: 321-608 & 322-057 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: Authorized Name and Digital Signature with Date: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 0 334 Taylor Wellman twellman@hilcorp.com 777-8449Authorized Title: Operations Manager 558 Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureGas-Mcf MD 112' 5,570' 8,880' Structural TVD 112' 380200 0 0 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 474 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 197-074 50-029-22762-00-00 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025509 & ADL0388235 MILNE POINT / KUPARUK RIVER OIL Hilcorp Alaska LLC 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: MILNE PT UNIT F-05 measuredPlugs Junk measured N/A Length 112' 5,570' 8,880' Size Collapse 470psi 3,090psi 5,410psi measured true vertical Casing 4,576' 7,444' 5,750psi 7,240psi Burst 1,490psi Conductor Surface 20" 9-5/8" 7" Form 10-404 Revised 10/2021 Submit Within 30 days of Operations By Meredith Guhl at 11:03 am, Mar 31, 2022 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2022.03.31 10:42:08 -08'00' David Haakinson (3533) _____________________________________________________________________________________ Revised By: TDF 3/8/2022 SCHEMATIC Milne Point Unit Well: MP F-05 / L1 / L1-01 Last Completed: 3/5/2022 PTD: 197-074 / 221-014 / 221-015 2-3/8” XO Slotted to Solid Liner @ 9,584’ (F-05L1-01) Whipstock (L1) set in 3-1/4” @9,430’ TD =8,895’ (MD) / TD = 7,459’(TVD) 20” Top of Whipstock @ 8,365’ Orig. KB Elev.: 41.3’/ GL Elev.: 12.3’ 7” 10 & 11 8 3 6 & 7 14 15 16 9 13 12 9-5/8” ES Cementer @ 2,005 MD 9-5/8” 1 2 Top of 4-1/2” Tubing cut @ 8,145’ 12-4-2021 KUP A3 Sands Top of 3-1/4” Liner @ 8,310’ Liner top Packer @8,316’ PBTD =8,797’(MD) /PBTD = 7,361’(TVD) 4 & 5 Top of 2-3/8” Liner @ 8,318’17 KUP A2 Sands KUP A1 Sands Two 7” x 21’ Marker Joints f/ 8,273’ – 8,314’ RKB 8 & 9 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 9-5/8" Surface 40 / L-80 / Btrc. 8.679 Surface 5,570’ 7" Production 26 / L-80 / Btc Mod 6.276 Surface 8,880’ L1: 3-1/4” Solid Liner 6.6 / L-80 / TCII 8,310’ 9,690’ L1-01: 2-3/8” Solid/Slotted Liner 4.7 / L-80 / STL & H511 8,318’ 11,210’ TUBING DETAIL 2-7/8” Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 8,123’ 4-1/2" Tubing 12.6 / L-80 / TXP 3.958” 8,145’ 8,316’ WELL INCLINATION DETAIL KOP @ 2,000’ Max Hole Angle = 61 deg. @ 5,220’ F-05L1 window @ 8,374’, F-05L1-01 window @ 9,378’ TREE & WELLHEAD Tree Cameron 4-1/16” 5M Wellhead 11” x 11” 5K FMC Gen 5A, w/ 4-1/2” Atlas Bradford hgr. Tbg Hanger 4-1/2” TC-1A-EMS 11 x 4-1/2” Atlas Bradford TC-II, 12.6# top & bottom GENERAL WELL INFO API: 50-029-22762-00-00 / 60-00 / 61-00 Drilled and Cased by Nabors 22E - 5/7/1997 1st Perforated w/ Wireline – 5/18/1997 RWO Tubing Swap: 3/12/2021 L1 & L1-01 Sidetrack: 5/21/2021 JEWELRY DETAIL No Depth Item 1 198’ Sta. 2: 2-7/8" GLM W/ dual port OV 2 7,939’ Sta. 1: 2-7/8" GLM W/ 1" Dummy Valve 3 7,996’ 2-7/8” XN Nipple – ID= 2.205” No-Go 4 8,047’ Discharge Head: B/O PMP 513 2-7/8 X 8 EUE 5 8,048’ Zenith Ported Sub: PRESS PORT 513/538P PMP 6 8,043’ Pump #2: 538PMSXD FLEX27 82 FER H6 STD_PNT 7 8,066’ Pump #1: 538PMSXD 068 G31 M FER NO_PNT 8 8,082’ Gas Separator: 538GSTHVEVX MT H6 FER STD PNT 9 8,087’ Bolt on Intake: GPXARCINT FER H6 10 8,088’ Upper Tandem Seal: GSB3DB H6 SB/AB PFSA 11 8,095’ Lower Tandem Seal: GSB3DB H6 SB/AB PFSA 12 8,102’ Motor: 562XP 250 Hp/2,505 V/61 A 13 8,118’ Sensor Gauge w/ Centralizer – Btm @ 8,123’ 14 8,154’ 4-1/2” x 7” Baker Premier Production Packer 15 8,225’ X Nipple, ID = 3.813” 16 8,276’ WELG, bottom at 8,316’**SEE NOTE** 17 8,316’ 2-3/8” Baker Liner Top Packer Bottom of 3-1/4” Protection String @ 9,690’ Packer Whipstock (L1- 01) set in 3-1/4” NOTE: Per CTD GR/CCL Tie-In log, Tubing tail 38’ deeper @ 8,354’ MDF-05L1-01 TD = 11,210’ (MD) / 7,157’ (TVD) PB TD = 11,210’ (MD) / 7,157’ (TVD) F-05L1 TD = 10,817’ (MD) / 7,189’ (TVD) PBTD = 10,817’ (MD) / 7,189’ (TVD) PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status F-05: Kup A3 8,460’ 8,472’ 7,024’ 7,036’ 12 5/31/2005 Closed F-05: Kup. A2 8,478’ 8,498’ 7,042’ 7,062’ 20 5/18/1997 Closed F-05: Kup. A1 8,503’ 8,523’ 7,067’ 7,087’ 20 5/31/2005 Closed F-05L1: Kup A 9,429’ 10,817’ 7,103’ 7,189’ 1,388 5/14/2021 Closed F-05L1-01: Kup A 9,584’ 11,209’ 7,146’ 7,157’ 1,625 5/19/2021 Open OPEN HOLE / CEMENT DETAIL 24" Cmt w/ 250 sks of Arcticset I (Approx.) 12-1/4" Cmt w/ 1,436 sks PF ‘E’, 600 sx Class ‘G’ 8-1/2” Cmt w/ 250 sks Class ‘G’ 4-1/4” x 3” Uncemented Solid / Slotted Liner (MPU F-05L1 & L1-01) Well Name Rig API Number Well Permit Number Start Date End Date MP F-05 ASR #1 50-029-22762-00-00 197-074 1/5/2022 3/5/2022 1/5/2021 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Plan and prep for Well Kill. Continue maintenance projects at A Pad, Mobilize 8.6 ppg Brine KWF and LRS for Well Kill. Spot and RU LRS. PT lines to 250/2500 psi (good test). Initial well pressures: tubing = 50 psi, IA = 5 psi & OA = 1 psi. Attempt to any gas off the tubing and IA , fluid observed at surface. Pump 10 bbls, 70° diesel spear down tbg @ 5 BPM, 275-375 psi. Swap to 8.6 ppg NaCl brine and continue pump down tbg, line up to take returns from IA to Kill tank. 4.5 BPM, ICP = Tbg @ 409 psi, IA @ 76 psi, OA @ 2 psi. Returns to tank observed with 9 bbls pumped. 30 bbls pumped, 4.7 BPM, Tbg @ 505 psi, IA @ 116 psi OA @ 3 psi. 50 bbls pumped, 4.7 BPM, Tbg @ 486 psi, IA @ 122 psi OA @ 10 psi. 25 bbls return,75 bbls pumped, 4.8 BPM, Tbg @ 402 psi, IA @ 142 psi OA @ 28 psi. 100 bbls pumped, 4.8 BPM, Tbg @ 305 psi, IA @ 149 psi OA @ 49 psi. 67 bbls return (~15% losses). 125 bbls pumped, 4.9 BPM, Tbg @ 137 psi, IA @ 173 psi OA @ 81 psi. 200 bbls pumped, 4.95 BPM, Tbg @ 175 psi, IA @ 288 psi OA @ 136 psi. 165 bbls return. 250 bbls pumped, 4.4 BPM, Tbg @ 143 psi, IA @ 232 psi OA @ 194 psi. 208 bbls return,275 bbls pumped, 4.5 BPM, Tbg @ 187 psi, IA @ 130 psi OA @ 272 psi. 300 bbls pumped, 3.9 BPM, Tbg @ 185 psi, IA @ 59 psi OA @ 337 psi. 247 bbls return. 351 bbls pumped, 3.9 BPM, Tbg @ 186 psi, IA @ 75 psi OA @ 383 psi. 292 bbls return. Shut down and line up to bullhead down tubing. SITP @ 11 psi, IA @ 24 psi, OA @ 380 psi, Bullhead 20 bbls, 8.6 ppg brine down Tbg, ICP 2.25 BPM - 700 psi, FCP @ 1.8 BPM - 880 psi Tbg, 880 psi IA. Shut in & monitor pressure. Drop from 410 to 190 psi on both Tbg & IA in 10 min and stabilized. Bleed down and monitor. Pressure build and stabilize @ 55 psi in 15 min. Bleed down and monitor. Pressure build and stabilize @ 23 psi in 15 min. Bleed down and monitor. Pressure build and stabilize @ 12 psi in 15 min, Bleed down and monitor. Pressure build and stabilize @ 210 psi in 5 min. Discuss operation and plan forward with Engineer. Bleed IA pressure down to 120 psi and shut in. Pressure build back to 210 psi and stabilize. Send trucks for more KWF while continue to discuss plan forward. Freeze protect surface lines and continue monitoring pressures. Well Name Rig API Number Well Permit Number Start Date End Date MP F-05 ASR #1 50-029-22762-00-00 197-074 1/5/2022 3/5/2022 Hilcorp Alaska, LLC Weekly Operations Summary 1/7/2021 - Friday Spot the crane & Fly the well house into position over well. Nipple down Tree. Inspect tubing hanger lift threads, dummy run XO in Hanger and install test plug in BPV. Set the BOP stack onto the wellhead and N/U. Fly rig floor onto Wellhouse. Continue N/U BOPE. Mobilize Rig & Mud Pits, and spot into position. Spot the pusher's shack, company man's shack & change room. Power cable to Co Man Shack damaged (cable pulled out from transformer.) Layout Koomey lines into insulated pipe and put heat to insulated system. Spot Glycol Heater and Mud Pump. Attempt to Level Rig and find air line froze up on air bag system, apply heat to lines and bags to thaw. Hook up Koomey lines and function test. Take on 9.6 ppg brine to pits. Heated lines did not solve air boot issue. VMS called out and find dump valves to be bad. While working through getting carriage lowered, Rig engine shut down and batteries did not have sufficient charge to re-start engine. Charge batteries and jump start engine. Warm hydraulic system and put heaters on ram cylinder bodies. Raise the Derrick into position and set up rig floor. Start filling air gaps, wrapping lines and put heat to necessary areas, install remaining stairs, landings and hand rails. 1/6/2021 - Thursday Line up and bleed off gas on tbg until good fluid. Bleed down tbg to 130 psi Shut in and line up to pump down tubing. Pressure increased to 244/232/4. Pump 8.6ppg brine down tbg taking returns up annulus @ 2 bpm 366 / 300 with choke cracked 2.5 bbls away, increase rate to 3 bpm 369 / 298 6 bbls away. 4bpm, 607 / 422 @ 67 away – crude in sample. Dirty 8.5 brine at 110 bbls away in sample. 548 / 444 @ 135 away, 577 / 490 @ 175 away, 175 pumped – 141 bbls returned to tank. 592 / 541 @ 250 away; Crude in sample, 575 / 446 @ 300 away, Contaminated brine in sample. 556 / 412 @ 325 away– 267 back to tank, Clean brine just under 8.6 ppg. 590 / 443 @ 550 away, Clean 8.6 ppg brine at sample ,Pump total 624 bbls / 517 bbls returned – shut down pumps. 44 / 15 / 418. Shut in well. Pressure build to, 230 / 227 after 2 min. 228 / 223 after 5 min,Baker read downhole gauge = 3217 psi. Discuss plan forward with Engineering team, received verbal authorization from AOGCC to proceed with 9.6 ppg Kill and complete as planned. Ordered out 9.6 ppg KWF fluid. Rig up vac trucks. Freeze protect well to ~1000’ with diesel: 20 bbls down IA with returns up tubing, 15 bbls bullheaded down tbg. Engineer received verbal authorization from AOGCC to proceed with 9.6 ppg Kill and complete Well as planned. Order out 9.6 ppg KW brine from MI, Mobilize ancillary equipment from A pad to F pad. Perform general housekeeping in A pad Tent. Wait on KWF, Rig up vac trucks. Initial tbg/IA/OA pressure at 449/330/-8. Line up & pump 25 bbls 9.6 ppg brine down tbg @ 4 BPM, taking returns from IA to kill tank to circulate out freeze protect. Swap over and pump 9.6 ppg brine down IA @ 4.2 BPM, taking returns up tbg holding 100-200 psi backpressure until KWF at tbg cut. Continue pumping at 4.2 BPM holding IA constant at ~350 psi. Good 9.5 ppg brine at surface with 325 bbls pumped / 285 bbls returned. Continue circulate @ 4.2 BPM until 450 bbls pumped / ~390 bbls returned. Shut down and monitor pressure. Initial SIP @ 67 psi on both tbg and IA, going on slight vac in 20 min. Freeze protect surface lines and 0.5 bbls down tbg & IA. Install BPV and rig down LRS, hardline and manifold trailer. Spot Mud boat and bring in crane to position equipment in place. Well Name Rig API Number Well Permit Number Start Date End Date MP F-05 ASR #1 50-029-22762-00-00 197-074 1/5/2022 3/5/2022 Hilcorp Alaska, LLC Weekly Operations Summary Continue rigging up on F-05 and troubleshooting issues with rig. VMS mechanic found small leak on HP fuel rail on rig engine. Operator smelled burning gear oil and observed gear oil in pan. Mobilize man lift to pull inspection plates and check gearbox. Rig up catwalk and make up spool sections for top of stack. Milne point electricians repaired electrical connection on company man trailer. Unable to use man lift once on location due to temperatures (-34° F), hydraulics to basket too cold to function properly. Troubleshoot heaters on cellar (intermittently shutting down). Make up BOPE test equipment. Check pressure on IA and record 230 psi @ 16:00, Addressing cold spots, tarp and heat due to -37° ambient temp. Put heat to stack and bring to operating temp of minimum 60°. P/U mandrel and M/U back Derrick HP hose. Lock in rams and prep for shell test. Flood system and check for leaks. Work air out of system. Close bag and observe a leak start on VBR actuator valve stem on accumulator manifold. SimOps: Monitor IA pressure. 345 psi @ 20:00, Retrieve new actuator valve from A pad storage tent and change out VRB actuator valve. SimOps: Swap heaters around to keep cellar/stack warmed. 5 heaters have quit working through the night. Monitor IA pressure. 475 psi @ 00:00, Work air from system and attempt BOPE Shell Test. Find a leak through a hole in the back Derrick High Pressure hose . Bleed pressures down, blow down like and change out high pressure hose. Attempt retest and experience leak at choke line connection from cellar hose to rig. Change out damaged Greylock gasket. Fill BOP stack w/ water attempt BOPE shell test on 2.875" test joint w/ annular - Pressure bleeding off slowly, continue isolating equipment to troubleshoot where pressure drop is coming from. SimOps: Monitor IA pressure. 490 psi @ 05:00. 1/8/2022 - Saturday 1/9/2022 - Sunday Continue troubleshooting pressure drop on Shell test and find the annular 4-way valve on accumulator to be leaking. Inspect valve and determine it needs to be replaced. SimOps: Continuous monitoring of IA pressure. 540 psi @ 08:40,Source a replacement 4-way accumulator valve and change out the leaking valve on unit. SimOps: Continuous monitoring of IA pressure. 560 psi @ 10:00, 610 psi @ 16:30,Top off stack w/ water, and purge air from system. Perform BOPE shell test on 2.875" test joint w/ annular - Good Test. Test BOPE as per Sundry and AOGCC reqmts. Pipe rams (2-7/8” x 5” VBR’s) with 2- 7/8” & 4-1/2” test joints, annular with 2-7/8” test joint. All tests performed with fresh H2O against test plug in BPV to 250 psi low &2500 psi high, for 5 charted min. Gas Alarms Tested. AOGCC rep Austin McLeod waived witness on 01/05/21 at 21:32 hours. Tests: 1. Annular with 2-7/8” test joint, 2-7/8" dart valve , C8, C9, C10 & K6 (passed),2. 2-7/8”x5” VBR with 2-7/8” test joint, C1 & K1 (Fail, Continue with testing while retrieve grease gun for valves), 3. 2-7/8”x5” VBR with 2-7/8” test joint, 2-7/8” FOSV, HCR Choke, K2 (passed), 4. 2-7/8”x5” VBR with 4-1/2” test joint, C1 & K1 (passed), 5. C5, C6, C9 & K3 (passed), 6. C4, C7 & C11 (passed), 7. C13, C14 & C15 (passed), 8. Blind Rams, C12 & C16 (fail/passed) Suspect air, retry with same results, grease valves and still slow bleed off on high test. Isolate k5 from line-up and obtain good test. K5 is not part of the BOP system. 9a. Manual adjustable choke (passed), 9b. Hydraulic super choke (passed),Accumulator Test: System pressure = 3050 psi, Pressure after closure = 1850 psi, 200 psi attained in 16 seconds, Full pressure attained in 67 seconds, N2 4 Bottle Average = 2310 psi, Close times: Annular = 26 sec, VBRs = 6 sec, HCR Choke = 1 sec, down test equipment, Blow down lines. Nipple up shooting flange for lubricator. Well Name Rig API Number Well Permit Number Start Date End Date MP F-05 ASR #1 50-029-22762-00-00 197-074 1/5/2022 3/5/2022 Hilcorp Alaska, LLC Weekly Operations Summary Continue rig down equipment. Lower mast and move rig to A-Pad. While nipple down BOPE, start to get crude out of opened mudcross valves. Close choke and kill valves, hook accumulator lines back up and close blind rams. Hook up gauge to kill line connection and monitor pressures. Reading 210 psi on tbg and IA on slight Vac @ 14:00. Discuss plan forward with Engineering team. Call out LRS, rig up and circulate 5 bbls heated diesel through BPV in attempt to seat poppit. 1 BPM – 275 psi. Shut down, bleed pressure and monitor. Tbg pressure climb back to 275 psi. Call out more 9.6 ppg KWF. Continuous monitoring of pressures at Tbg and IA. Tbg building 20-30 psi an hour. IA becoming static then start seeing same pressure trend @ 18:00. Crews perform maintenance and service on pump line valves & work on getting carriage of rig on A pad while waiting on KWF. Tbg build to 450 psi, IA at 105 psi. Rig up LRS and VAc trucks. PT lines. Hold PJSM with crew and LRS. Pump 9.6 ppg brine down tubing, take returns up IA out to kill tank holding 75-200 psi backpressure. ICP Tbg/IA = 750 psi/190 psi @ 5 BPM. FCP Tbg/IA = 530 psi / 131 psi @ 5 BPM. Mostly gas cut crude with intermittent spots of brine/crude/gas until 325 bbls pumped / 280 bbls returned, when returns started cleaning up to dirty 9.55 ppg brine. Pumped a total of 425 bbls with 370 bbls returned. Shut down, Freeze protect and blow down surface lines. Monitor Pressures. Tbg/IA - 87 psi/84 psi. IA on a Vac in 20 min, Tbg on Vac in 40 min. Verify no pressures and open blind rams. Pull BPV, install TWC and test to 1400 psi for 10 min. Good test;Start Nipple down BOPE Make up shooting flange and lubricator. Fill stack with diesel. Pressure up to test connections and experience a leak at the base of shooting flange connection. Re-torque bolts and obtain a good test. Lubricate out CTS plug from BPV. No pressure observed. Close blind rams to remove CTS plug from polished rod. Attempt to pull rod to rig floor and would not move. Troubleshoot and find that CTS plug had not been pulled up high enough in stack and blind rams were closed on plug. Verify no pressure below blind rams. Open rams and pull CTS plug to floor. Confirmed with damage to CTS plug threads that blind rams came in contact with plug. Suck diesel out of stack and visually inspect top of BPV for junk - Clean. Lower new CTS plug on lubricator polished rod and start 2 turns by hand. M/U lubricator and install CTS plug. Verify no pressures and remove lubricator. SimOps: Notification sent to AOGCC for re-test on blind rams @ 18:08 on 1/10/2022. Witness verbally waived via phone by AOGCC Rep Matt Herrera @ 18:35. Fill stack with water, purge air and troubleshoot leaking valve on pump line manifold. Test Blind Rams with fresh H20, against CTS plug in BPV to 250 psi low / 2500 psi high for 5 charted min each - Good Test. Blow down lines and offload 50 bbls brine from pits to LRS.,Hold PJSM with all parties involved. Lubricate out CTS plug. M/U up BPV running tool, and line up mud cross to the choke manifold with a closed superchoke. Equalize pressure and lubricate out BPV. Tubing pressure stabilized @ 765 psi. Bleed gas off tubing then line up LRS to pump down tubing. Circulate, 9.6ppg brine (first 50 bbls mixed with red marker dye) down tubing taking returns up IA, through choke manifold and out to kill tank, holding 100-200 psi back pressure. Pump @ 5 BPM – ICP Tbg/IA= 1557psi/1018psi, FCP Tbg/IA– 1219 psi/348psi First 260 bbls returns was mostly gassed up crude. Dirty 9.55ppg brine return @ 286 bbls pumped. Total of 411 bbls pumped and 315 bbls returned to tank. Red marker dye was not observed with returns to surface. Shut down and monitor pressures, gauge readings 28 psi on tbg & 10 psi on IA. Freeze protect and blow down surface lines. Rig down LRS. Monitor pressures, reading 0 on gauges after 30 min. Open superchoke to gasbuster and observe no flow. Both tubing and IA on a good Vac after 40 min. Pull old BPV from Lubricator, install New BPV. RDMO of F-05. Pull catwalk and stage on edge of pad. Start rig down rig floor equipment. Deenergize accumulator lines and prep to nipple down BOPE stack. 1/11/2022 - Tuesday 1/10/2022 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP F-05 ASR #1 50-029-22762-00-00 197-074 1/5/2022 3/5/2022 No operations to report. No operations to report. 1/15/2022 - Saturday No operations to report. 1/18/2022 - Tuesday 1/16/2022 - Sunday No operations to report. 1/17/2022 - Monday 1/14/2021 - Friday No operations to report. 1/12/2021 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Nipple down BOPE. Observe both hanger neck seals to be gone, suspect washed off and pumped downhole. Replace seals and Nipple up Tree. Test void 500/5000 psi, 5/15 min – Good Test.;Fly the celler hut off of the Well. Send Rig floor and Cellar hut to A pad. Position Mud Pits trailer behind doghouse and connect power.;Rig up LRS, Test lines and freeze protect Tbg & IA. 1/13/2021 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP F-05 Doyon 14 50-029-22762-00-00 197-074 2/24/2022 3/5/2022 Continue to RU, MU choke, gas buster U-tube line, water and bleeder lines under rig floor, welder repair suction valve linkage in pits- 4 total, take on 580 bbls 9.6 ppg brine to pits. Complete acceptance checklist. Accept rig @ 08:00 hrs. RU lubricator, pull BPV ae per WH rep, 300 psi on IA, 0 psi on tubing, secure tree, RD lubricator, install tree cap and gauge. Install containment and Lay 3x12 timbers over cellar box, RU squeeze manifold, manual choke and lines. Milne Point went f/ phase 2 to phase 1 conditions @ 10:30. Continue to RU manifold and lines in cellar to IA, tubing and flow back tank. Flood lines with water, test lines to 250 / 3500 psi, good, BD lines. Bleed off IA to FB tank from 300 to 0 psi, all air and some gas, no fluid, 0 psi on tubing. Pump 9.6 ppg Brine @ 4.5 BPM, down tubing taking returns from IA to flow back tank. Hold ~200 psi backpressure on IA for first 130 bbls, then hold Tbg constant until good 9.6+ brine returns. ICP: Tbg/IA = 400 psi/400 psi, FCP: Tbg/IA = 600psi/300psi. Diesel, Crude and gas for first 300 bbls then start seeing brine cut crude and good 9.6+ ppg. brine at 330 bbls away. Pumped a total of 362 bbls with 340 bbls returned. Shut down and monitor pressure. Initial SIP @ 75 psi on both tbg and IA. Blow down surface lines and swap gauges to low psi gauges for improved accuracy while monitoring pressure. Pressure dropping trending @ 25 psi/15min, tubing going on a vac in 45 min & IA become static. Wellhead rep install BPV. Rig down high-pressure lines & squeeze manifold. Rig up to fill IA. Clear and clean cellar area in prep for N/D tree. Nipple down tree & secure in cellar. Install CTS plug in BPV. Dummy run TC-II XO to gauge threads on hanger - 7 turns to seat. N/U BOP Stack. M/U kill line. Secure stack. Install riser. Charge accumulator. SimOps: Pump 10 bbls to IA every hour. Rig up testing equipment. Start loading shed with 2-7/8" tubing. Daily losses = 22 bbls, Total Losses = 22 bbls. Rig on Hi-Line @ 19:00. 2/26/2022 - Saturday 2/25/2021 - Friday Rig staged on F-Pad, clear snow and drifts from around F-05 and pad, place rig mats around well and for rig foot print. Simops: Hilcorp electricians run high line cable for rig. Continue to lay mats for rig foot print, place wellhead equipment, squeeze manifold and lines behind well. Note: MP in phase II weather conditions at 12:30. PJSM, align and spot the rig over F-05. Wells group set flow back tank and RU hardline. Skid rig floor into drilling position. Begin rigging up. R/U rig floor steam, water, air and high pressure mud lines. Start prepare mud pits for fluid. Lower stairways and install landings. Start M/U drag chain throughs. Finish M/U drag chain troughs. Continue prep pits for fluid, find broken valve linkage on Pit #4, C/O with PP linkage. Thaw ice plugs from pump suctions. Function shakers. Thaw and install cellar steam heaters. Start rigging up lines and squeeze manifold in cellar and lines to kill tank . Start offloading 9.6 ppg brine to mud pits. 2/23/2021 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 2/24/2021 - Thursday Finish skid rig floor into moving position. Move rig and stage at entrance of Pad & install boosters. BOP test 24 hr notice submitted to AOGGC @ 17:45, 02/24/2022. Move rig from M-Pad to F-Pad. Well Name Rig API Number Well Permit Number Start Date End Date MP F-05 Doyon 14 50-029-22762-00-00 197-074 2/24/2022 3/5/2022 Hilcorp Alaska, LLC Weekly Operations Summary Continue attempting to get shell test, pressure up, slight drip on flange between HCR and manual kill valve, bleed off and tighten same, Mechanical integrity inspect new weld on kill line target 90. Pressure up to 5000 psi, leaking on kill line in cellar @ 3 1/16'' x Oteco flange. Continue to fill IA every hr with 9.6 brine, taking 4 1/2 to 5 bph, BD line, disconnect XO flange on kill line, take to shop, welder replace 3'' Oteco flange. Mechanical integrity inspect weld. Reinstall XO flange on kill line, flood lines, pressure up to 5000 psi, slight leak on flange between manual and HCR choke, bleed off and tighten flange. Pressure up to 5000 psi, slight drip LPR door on DS, bleed off and tighten door. Perform shell test to 5000 psi, good. Continue to fill IA every hr with 9.6 brine, slowing to 3 bbls to fill ea. hr. Test BOPE on 2 7/8'' and 4 1/2'' test joints to 250 PSI low / 5000 PSI high. AOGCC rep Brian Bixby witness test. All tests performed with fresh water against a CTS plug in BPV. 1. Annular on 2.875" test joint, 2. Upper 2.875”x5” VBR on 2.875” test joint & choke valves 1, 12, 13, 14, kill Demco, 3.5" FOSV & Upper IBOP. Continue to fill IA every hr with 9.6 brine, 3. Choke valves 9, 11, HCR kill & 3.5" dart valve & lower IBOP, 4. Choke valves 5, 8, 10, manual kill & 5” FOSV - Manual Kill Fail/Pass (Grease and Function Valve), 5. Choke valves 4, 6, 7 & 5" dart valve, 6. Choke valves 2, Test multi position lock on UPR with Accumulator bled down , 4" Oteco on Choke line at rig floor leaking, start troubleshooting. Perform Accumulator test: 3000 PSI sys pressure, 1650 PSI after closure, 200 PSI recovery in 42 sec, full recovery in 195 sec, 6 N2 bottle avg = 2100 PSI. Bag close in 13 sec, UPR close in 8 sec, LPR close in 7 sec, HCR’s close in 3 sec/ea. Rig electrician tested rig gas alarms. Change out Oteco clamp & gasket on choke line at rig floor. Fill lines & purge air from system. Pressure up to 5k psi and observe leak on choke line Oteco under rig floor. Torque bolts on Oteco clamp and re- test to 5k psi. Oteco connection under rig floor still leaking & observe leak on manual choke flange t/ BOP stack. Bleed of pressures. Torque bolts on choke flange at BOP stack. Decision made to have welder replace full Oteco connections both above and below rig floor. Start disassemble and pull choke hardline from choke manifold to cellar, and send to rig shop for welder to repair. Daily Losses = 76 bbls. Total Losses = 215 bbls. IA become static @ 23:00 and start building pressure slowly @ 01:00. Reading 5 psi @ 04:00. 2/27/2022 - Sunday Continue to NU BOPE, torque flange bolts, MU kill line, secure stack, install riser, load test equipment and safety valves to rig floor. Continue to pump 10 bbls 9.6 brine to IA every hr. Fill stack with fresh water, RU test equipment with 2 7/8'' test joint and XOs, flood lines and choke, prep to perform shell test. Mechanic troubleshoot annular valve on accumulator, inspect valve, hydraulic lines to annular full of air, purge lines with koomey fluid, operating correctly. Finish RU test equipment, pressure up to shell test, choke and kill line hose leaking at flanges, inspect oteco flanges, C/O clamps and gaskets on kill line target 90, replace oteco gasket on choke hose. Pressure up and oteco still leaking @ 3000 psi. Remove kill line oteco target 90. SimOps: Cont processing 2-7/8" tubing. Fill IA every hr. General housekeeping around rig. M/U new Oteco 90 on kill line. C/O suction manifold gasket on test pump. SimOps: Cont processing 2-7/8" tubing. Fill IA every hr. General housekeeping around rig. Fill lines and purge air from system. Line up and attempt shell test. Observe leak on choke line Oteco connection at rig floor. Blow down choke line, break oteco connection on choke line, clean and inspect flange faces. Replace oteco gasket ring and M/U oteco connection. Attempt shell test and observe leak at head pin on Test jt. Change out 1502 gasket test cap & fittings. Purge air from system. 2/28/2022 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP F-05 Doyon 14 50-029-22762-00-00 197-074 2/24/2022 3/5/2022 Hilcorp Alaska, LLC Weekly Operations Summary Disassemble and pull choke hardline from choke manifold to cellar, send upper section to rig shop for welder to repair, NES welder on location, replace end of flange on choke line in the pits, while welders working open LPR to doors to inspect ram, due to previously not being able to pressure up for test. Continue to monitor IA, building pressure slowly from 20 psi to 45 psi. Welders continue to weld out installing new choke Oteco flanges. Inspect lower pipe rams, good shape, close doors and button up same, clean scale and debris from suction and lines on test pump. Continue to monitor IA, building pressure slowly from 45 psi to 80 psi. Mistras X-Ray inspect new flange welds. Install repaired choke lines. R/U test equipment and flood lines. Purge air from system and obtain a good shell test on BOPE, 250 psi / 5000 psi. Test BOPE on 2 7/8'' and 4 1/2'' test joints to 250 PSI low / 5000 PSI high. AOGCC rep Brian Bixby witness test. All tests performed with fresh water against a CTS plug in BPV. 1. Upper 2.875”x5” VBR on 4.5” test joint & choke valves 1, 12, 13, 14, kill Demco, 3.5" FOSV & 5" FOSV, 2. Choke valves 9,11, HCR Kill, 3.5" Dart Valve & 5" Dart Valve, 3. Choke valves 5, 8, 10 & Manual Kill, 4. Choke valves 4,6 & 7, 5. Choke Valve 2, 6. HCR Choke - Failed, 7. Lower 2.875”x5” VBR on 4.5” test joint - Ram locks tested. Test continues on next report. Daily Losses = 0 bbls, Total Losses = 215 bbls. IA building pressure . Reading 135 psi. 3/1/2022 - Tuesday Well Name Rig API Number Well Permit Number Start Date End Date MP F-05 Doyon 14 50-029-22762-00-00 197-074 2/24/2022 3/5/2022 3/2/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Continue to test BOPE, Test BOPE on 2-7/8" and 4-1/2" test joints to 250 PSI low / 5,000 PSI high. Test annular on the 2-7/8" test jt to 250 PSI low / 3,500 PSI high 5 min ea, AOGCC rep Brian Bixby witness test. All tests performed with fresh water against a CTS plug in BPV. Chart all tests. Failed tests - HCR choke, 2-7/8" X 5" LPR on 2-7/8" test joint, Lower IBOP, annular 4- way valve on the accumulator. Continue to monitor IA, building pressure slowly . Reading 160 psi. Drain stack and blow down lines, Rig mechanic inspect 4 way valve on accumulator for annular, good-found annular KR valve on accumulator was the issue, it failed due to air in the annular hyd lines, install new KR and barks-dale valve. BD annular hyd line, welder repair pinhole on line, purge air from annular and lines. Open doors and remove LPRs. Install spare 2-7/8" x 5" VBRs and button up doors. Remove HCR choke and install new. Breakout/remove Lower IBOP and install spare. IA pressure = 315 psi. RU to test BOPE, MU 4-1/2" test joint and flood lines. Purge air from the system. Continue to test BOPE to 250/5,000 psi with 2-7/8" and 4-1/2" test joints. 1. LPR (2-7/8" x 5" VBR) with 4-1/2" test joint and Lower IBOP (passed). 2. LPR (2-7/8" x 5" VBR) with 2-7/8" test joint (passed). 3. Annular to 250/3,500 psi with 2-7/8" test joint (passed). 4. Choke Line (passed) . 5. HCR Choke (passed). Blow down and RD BOPE testing equipment. MU dry rod and pull CTS plug from BPV. PU and install the Dutch riser. PU the lubricator. Attempt to RILDS on the Dutch riser but the LDS are seized. Lay down the lubricator and Dutch riser. 3/3/2022 - Thursday R/U squeeze manifold, manual choke and lines in the cellar from IA to flow back tank, test lines to 3,000 psi, BD same, RU to lubricate out BPV, secure lubricator, close annular, increase annular pressure to 1,000 psi. Pressure test lubricator. Bleed IA to flowback tank thru squeeze manifold and choke from 440 psi to 0 psi, shut in IA, Pull BPV above blind rams, close blinds, 500 psi on tbg, bleed off and RD lubricactor. PJSM, Bleed off IA to flow back tank from 440 psi to 0 psi, Pump 9.6 ppg Brine @ 4.5 BPM, down tubing taking returns from IA to flow back tank. Hold ~200 psi backpressure on IA for first 130 bbls, then hold Tbg constant until good 9.6+ brine returns. ICP: Tbg/IA = 470 psi/480 psi, FCP: Tbg/IA = 600psi/400psi. Crude, gas, and gas cut brine for first 290 bbls then start seeing good 9.6+ ppg. brine at 300 bbls,. Pumped a total 340 bbls, 301 bbls returned to flowback tank. shut down and shut in IA and tubing, BD line to flowback tank. Line up and bullhead 40 bbls down IA, 2 bpm 300 psi, 2.5 bpm 550-2130 psi, 2.7 bpm 2,130 psi-2300 psi, shut off pump, shut in IA. Line up and bullhead 40 bbls down tubing, 2 bpm 550 psi, 3 bpm 1,950-2,000 psi, shut off pump. Shut in and monitor tbg and IA and let relax, bleed off 50 psi from tbg and 100 psi from IA. Monitor well while RU handling equipment, double stack power tongs, centrilift spooler on the rig floor, ready FOSV on landing joint. Tubing and IA static at 16:00 and on a vac at 17:30. Continue to RU to pull the completion. Blow down circulating lines in the cellar. Open the blinds. Blow down the choke and kill lines. Turn on the hole fill, took 15 bbls to fill. MU the TIW to the landing joint. MU the landing joint to the tubing hanger. BOLDS. PJSM for pulling tubing hanger and laying down 4-1/2" tubing. PU, unseat the tubing hanger and pull to the rig from 8,145' to 8,115' (PU = 115K). Lay down the tubing hanger and landing joint. Change crossover on the TIW to 4-1/2" TXP and change elevators. Well out of balance. MU TIW and head pin. RU circulating equipment. Circulate 1 tubing volume (124 bbls) at 5 BPM = 450 psi. RD circulating equipment while monitoring the well for flow. The well is on a slight vac. POOH laying down 4-1/2" TXP tubing while spooling TEC line and removing cannon clamps from 8,115' to 3,454'. Well Name Rig API Number Well Permit Number Start Date End Date MP F-05 Doyon 14 50-029-22762-00-00 197-074 2/24/2022 3/5/2022 Hilcorp Alaska, LLC Weekly Operations Summary Continue to RIH per tally with ESP completion on 2-7/8", 6.5#, L-80, EUE 8rd tubing spooling ESP cable and installing cannon clamps and testing electrical continuity every 2,000' from 4,087' to 5,584'. Loss rate while RIH = 7.5 BPH. Hydraulic hose failed under the rig floor that supplies the rig floor hydraulics, shut down hydraulic pump, set pipe in slips, install FOSV, approximately 15 gallons released into containment. Rig mechanic replace hose, good. notifications made, hydraulic fluid in containment cleaned up. Monitor the well with continuous hole fill, Loss rate = 7 BPH. L/D FOSV, continue RIH per tally with ESP completion from 5,584' to 5,826' @ joint #189' spooling ESP cable. Loss rate while RIH = 7-8 BPH. Install FOSV, centrilift RU and splice ESP cable, Meg test cable to check electrical continuity, good. RIH per tally with ESP completion from 5,826' to 5,952' . Monitor the well with continuous hole fill, Loss rate = 7 BPH. Continue to RIH per tally with ESP completion on 2-7/8", 6.5#, L-80, EUE 8rd tubing spooling ESP cable and installing cannon clamps from 5,826' to 5,952'. Backstop for the pipe skate quit working, install FOSV, Rig electrician troubleshoot pipe skate backstop, failed wire to solenoid for backstop up/down control, replace same. Monitor well, losses continue at 7 BPH. Continue to RIH per tally with ESP completion on 2-7/8", 6.5#, L- 80, EUE 8rd tubing spooling ESP cable and installing cannon clamps and testing electrical continuity every 2,000' from 5,092' to 8,089'. Loss rate = 7 BPH. PU the tubing hanger and install the BPV. MU the landing joint. Terminate the ESP cable and splice to the tubing hanger penetrator. Connect ESP cable umbilical. RIH, MU an additional joint for landing and land the tubing hanger. Test electrical continuity - good. RILDS. PU = 91K and SO = 76K. Lay down the landing joint. Blow down the choke, kill and hole fill line. Clean and clear the floor. Pull the master bushings, pull the riser and reinstall the master bushings. ND Dutch riser flange to get the LDS worked on at the shop. ND the BOP stack, set back and secure for transport. Clean the top of the tubing hanger and wellhead. Remove the ESP cable umbilical. Install the CTS plug into the BPV. Mobilize the tree into the cellar. NU the tree. PT the tubing hanger void to 250/5,000 psi for 10 minutes each (good test). Rig released at 06:00 hours. 3/5/2022 - Saturday 3/6/2022 - Sunday No operations to report. 3/4/2022 - Friday Continue to POOH laying down 4-1/2" TXP tubing while spooling TEC line and removing cannon clamps from 3454' to surface. Recovered total 200 joints tubing, 105 canon clamps, X nipple assembly, jet pump with gauge assembly and cut joint = 1.98' (good cut. photos in well folder). Use continuous hole fill, 9-10 BPH loss rate while POOH (losses = 91.6 bbls). Hilcorp enviro test tubing for NORM,. Clear and clean the rig floor. RD 4-1/2'' handling equipment. RU 2-7/8" handling equipment. Monitor well using continuous hole fill, 8-9 BPH loss rate. Continue to RU 2-7/8" handling equipment. RU ESP cable spooler, hang sheave in the derrick, ready FOSV and XO. Pull ESP cable thru sheave and secure same. RU power tongs. Monitor well using continuous hole fill, 9 BHP loss rate. PJSM with centrilift and rig crew. PU motor gauge/motor assembly and MU the centralizer. Service the motor. PU and MU the lower & upper tandem seal sections, intake and gas separator. Service the seals. PU and MU pumps 1 & 2, Zenith ported sub, discharge head and pup joint. Monitor well using continuous hole fill, 9 BHP loss rate. MU gauge control line and MLE. Monitor well using continuous hole fill, 7 BHP loss rate. Splice MLE to the ESP cable. Test of electrical continuity good. Monitor well using continuous hole fill, 7 BHP loss rate. 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ŽƵďůĞŐĂƚĞƌĂŵƐŚŽƵůĚďĞĚƌĞƐƐĞĚǁŝƚŚ ϮͲϳͬϴ͟ǆϱ͟sZƐ ŝŶƚŽƉĐĂǀŝƚǇ͕ďůŝŶĚƌĂŵ ŝŶďŽƚƚŽŵĐĂǀŝƚǇ͘ x ^ŝŶŐůĞƌĂŵĐĂŶďĞĚƌĞƐƐĞĚǁŝƚŚ ϮͲϳͬϴ͟ǆϱ͟sZƐ͘ ϮϬ͘ dĞƐƚKWƚŽϮϱϬͬϯ͕ϬϬϬƉƐŝĨŽƌϱͬϱŵŝŶ͘dĞƐƚĂŶŶƵůĂƌƚŽϮϱϬͬϮ͕ϱϬϬƉƐŝĨŽƌϱͬϱŵŝŶ͘ Ă͘ EŽƚŝĨǇƚŚĞK'ϮϰŚŽƵƌƐŝŶĂĚǀĂŶĐĞŽĨKWƚĞƐƚ͘ ď͘ dĞƐƚƵƉƉĞƌϮͲϳͬϴ͟ǆϱ͟ƌĂŵƐǁŝƚŚƚŚĞϮͲϳͬϴ͟ĂŶĚϰͲϭͬϮ͟ƚĞƐƚũŽŝŶƚƐ͘ Đ͘ ŽŶĨŝƌŵƚĞƐƚƉƌĞƐƐƵƌĞƐǁŝƚŚƉƉƌŽǀĞĚ^ƵŶĚƌǇ͘ Ě͘ ŶƐƵƌĞƚŽŵŽŶŝƚŽƌƐŝĚĞŽƵƚůĞƚǀĂůǀĞƐĂŶĚĂŶŶƵůƵƐǀĂůǀĞƉƌĞƐƐƵƌĞŐĂƵŐĞƐƚŽĞŶƐƵƌĞ ŶŽƉƌĞƐƐƵƌĞŝƐƚƌĂƉƉĞĚƵŶĚĞƌŶĞĂƚŚƚĞƐƚƉůƵŐ͘ Ğ͘ KŶĐĞKWƚĞƐƚŝƐĐŽŵƉůĞƚĞ͕ƐĞŶĚĂĐŽƉǇŽĨƚŚĞƚĞƐƚƌĞƉŽƌƚ;ϭϬͲϰϮϰĨŽƌŵͿƚŽK' ĂŶĚƚŽǁŶĞŶŐŝŶĞĞƌ͘ Ϯϭ͘ ůĞĞĚĂŶǇƉƌĞƐƐƵƌĞŽĨĨĐĂƐŝŶŐƚŽƚŚĞƌĞƚƵƌŶƐƚĂŶŬ͘WƵůůd^ƉůƵŐĂŶĚWs͘ ϮϮ͘ ^ŚƵƚƚŚĞďůŝŶĚƐĂŶĚĐŝƌĐƵůĂƚĞǁĞůůǁŝƚŚϯϬϬďďůƐŽĨϵ͘ϲƉƉŐďƌŝŶĞ͘^ŚƵƚŝŶƌĞƚƵƌŶƐĂŶĚďƵůůŚĞĂĚĚŽǁŶ ƚŚĞƚďŐĨŽƌϰϬďďůƐĂŶĚƚŚĞŶďƵůůŚĞĂĚĚŽǁŶƚŚĞ/ĨŽƌϰϬďďůƐƚŽĞŶƐƵƌĞǁĞůůŝƐĚĞĂĚ͘KƉĞŶďůŝŶĚƐ͘ Ϯϯ͘ DhůĂŶĚŝŶŐũŽŝŶƚŽƌƐƉĞĂƌĂŶĚWhŽŶƚŚĞƚƵďŝŶŐŚĂŶŐĞƌ͘ Ă͘ dŚĞWhǁĞŝŐŚƚŝƐĞƐƚŝŵĂƚĞĚĂƚϭϮϱ<ůďƐ͘ Ϯϰ͘ ZĞĐŽǀĞƌƚŚĞƚƵďŝŶŐŚĂŶŐĞƌ͘ ZtKʹ:WƚŽ^W ZĞǀŝƐŝŽŶϮʹϬϮͬϬϳͬϮϬϮϮ tĞůů͗DWh&ͲϬϱ Ϯϱ͘ WKK,ĂŶĚůĂǇĚŽǁŶƚŚĞϰͲϭͬϮ͟ƚƵďŝŶŐ;ϭϬϱĐĂŶŶŽŶĐůĂŵƉƐͿ͘ůůƚƵďƵůĂƌƐƌĞĐŽǀĞƌĞĚǁŝůůďĞũƵŶŬĞĚ͕ /ŶƐƉĞĐƚƚŚĞƉƌŽĨŝůĞ͕ĐĂŶŶŽŶĐůĂŵƉƐ͕ƐůŝĚŝŶŐƐůĞĞǀĞĂŶĚŐĂƵŐĞƐĨŽƌŝŶǀĞŶƚŽƌǇ͘ Ă͘ tŚŝůĞWKK,͕ůŽĂĚǁĞůůĚŽǁŶƚŚĞ/ƚŽĐŽŶĨŝƌŵĂŶĚŵŽŶŝƚŽƌůŽƐƐƌĂƚĞ͘>ŽƐƐƌĂƚĞŽĨϱ͘ϴďƉŚ ǁĞƌĞŽďƐĞƌǀĞĚƉŽƐƚǁĞůůŬŝůůĚŝĂŐŶŽƐƚŝĐƐƉĞƌĨŽƌŵĞĚŽŶϬϭͬϭϱͬϮϬϮϮ͘^ĞĞt^ZĨŽƌĨƵůů ĚĞƚĂŝůƐ͘ Ϯϲ͘ WhŶĞǁ^WĂŶĚZ/,ŽŶϮͲϳͬϴ͟ϲ͘ϱη>ͲϴϬƚƵďŝŶŐ͘ŚĞĐŬĞůĞĐƚƌŝĐĂůĐŽŶŶĞĐƚŝŽŶƐĞǀĞƌǇϮ͕ϬϬϬ͛ Ă͘ ĂƐĞŽĨ^WĂƚцϴ͕ϭϬϬ͛D ď͘ ϭũŽŝŶƚƐŽĨϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐ Đ͘ ϮͲϳͬϴ͟yE;Ϯ͘ϮϬϱ͟EŽͲ'ŽͿEŝƉƉůĞ Ě͘ ϭũŽŝŶƚŽĨϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐ Ğ͘ >ŽǁĞƌϮͲϳͬϴ͟ǆϭ͟^ŝĚĞͲƉŽĐŬĞƚ'>DǁŝƚŚƵŵŵǇ'>s Ĩ͘ DƵůƚŝƉůĞũŽŝŶƚƐϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐ Ő͘ hƉƉĞƌϮͲϳͬϴ͟ǆϭ͟^ŝĚĞͲƉŽĐŬĞƚ'>DΛцϮϬϬ͛DǁŝƚŚϬ͘Ϯϱ͟Ks Ś͘ цϱũŽŝŶƚƐϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐ Ϯϳ͘ >ĂŶĚƚƵďŝŶŐŚĂŶŐĞƌ;ĂƵƚŝŽŶŶŽƚƚŽĂŵĂŐĞĂďůĞǁŚŝůĞůĂŶĚŝŶŐƚŚĞŚĂŶŐĞƌͿ͘>ĂǇĚŽǁŶůĂŶĚŝŶŐ ũŽŝŶƚ͘EŽƚĞWh;WŝĐŬhƉͿĂŶĚ^K;^ůĂĐŬKĨĨͿǁĞŝŐŚƚƐŽŶƚĂůůǇ͘ Ϯϴ͘ ^ĞƚWs͘ WŽƐƚͲZŝŐWƌŽĐĞĚƵƌĞ͗ tĞůů^ƵƉƉŽƌƚ ϭ͘ ZŵƵĚďŽĂƚ͘ZKWŚŽƵƐĞ͘DŽǀĞƚŽŶĞǆƚǁĞůůůŽĐĂƚŝŽŶ͘ Ϯ͘ ZhĐƌĂŶĞ͘EKW͘ ϯ͘ EhĞǆŝƐƚŝŶŐϯͲϭͬϴ͟ϱ͕ϬϬϬηƚƌĞĞͬĂĚĂƉƚĞƌĨůĂŶŐĞ͘dĞƐƚƚƵďŝŶŐŚĂŶŐĞƌǀŽŝĚƚŽϱϬϬƉƐŝůŽǁͬϱ͕ϬϬϬƉƐŝ ŚŝŐŚ͘WƵůůWs͘ ϰ͘ ZĐƌĂŶĞ͘DŽǀĞϱϬϬďďůƌĞƚƵƌŶƐƚĂŶŬĂŶĚƌŝŐŵĂƚƐƚŽŶĞǆƚǁĞůůůŽĐĂƚŝŽŶ͘ ϱ͘ ZĞƉůĂĐĞŐĂƵŐĞ;ƐͿŝĨƌĞŵŽǀĞĚ͘ ϲ͘ dƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶ͘ZhǁĞůůŚŽƵƐĞĂŶĚĨůŽǁůŝŶĞƐ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƐͲďƵŝůƚ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ KW^ĐŚĞŵĂƚŝĐ ϰ͘ ϰ͘ϱ͟dƵďŝŶŐdĂůůǇ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗d&ϭϭͬϯϬͬϮϬϮϭ ^,Dd/ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DW&ͲϬϱͬ>ϭͬ>ϭͲϬϭ >ĂƐƚŽŵƉůĞƚĞĚ͗ϯͬϭϮͬϮϬϮϭ Wd͗ϭϵϳͲϬϳϰͬϮϮϭͲϬϭϰͬϮϮϭͲϬϭϱ ´;26ORWWHG WR6ROLG/LQHU# ¶)/ :KLSVWRFN /VHWLQ ´ #¶)/ 7' ¶0'¶79' 3%7' ¶0'¶79' )/ 7' ¶0'¶79' 3%7' ¶0'¶79' dсϴ͕ϴϵϱ͛;DͿͬdсϳ͕ϰϱϵ͛;dsͿ ϮϬ´ 7RSRI :KLSVWRFN# ¶ KƌŝŐ͘<ůĞǀ͗͘ϰϭ͘ϯ͛ͬ'>ůĞǀ͗͘ϭϮ͘ϯ͛ ϳ͟ ´(6 &HPHQWHU # 0' ϵͲϱͬϴ͟ .83$ 6DQGV 7RSRI ´ /LQHU# ¶ /LQHUWRS 3DFNHU #¶ Wdсϴ͕ϳϵϳ͛;DͿͬWdсϳ͕ϯϲϭ͛;dsͿ 7RSRI´ /LQHU# ¶ .83$6DQGV .83$6DQGV 7ZR´ [¶0DUNHU -RLQWVI¶± ¶5.% ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϭ͘ϭͬ,ͲϰϬͬEͬ Eͬ ^ƵƌĨĂĐĞ ϭϭϮΖ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬƚƌĐ͘ ϴ͘ϲϳϵ ^ƵƌĨĂĐĞ ϱ͕ϱϳϬ͛ ϳΗ WƌŽĚƵĐƚŝŽŶ Ϯϲͬ>ͲϴϬͬƚĐDŽĚ ϲ͘Ϯϳϲ ^ƵƌĨĂĐĞ ϴ͕ϴϴϬ͛ >ϭ͗ϯͲϭͬϰ͟ ^ŽůŝĚ>ŝŶĞƌ ϲ͘ϲͬ>ͲϴϬͬd// ϴ͕ϯϭϬ͛ ϵ͕ϲϵϬ͛ >ϭͲϬϭ͗ϮͲϯͬϴ͟ ^ŽůŝĚͬ^ůŽƚƚĞĚ>ŝŶĞƌ ϰ͘ϳͬ>ͲϴϬͬ^d>Θ,ϱϭϭ ϴ͕ϯϭϴ͛ 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Chmielowski Date: 2021.12.02 09:49:39 -09'00' RBDMS HEW 12/7/2021 ZtKʹ:WƚŽ^W tĞůů͗DWh&ͲϬϱ tĞůůEĂŵĞ͗DWh&ͲϬϱ W/EƵŵďĞƌ͗ϱϬͲϬϮϵͲϮϮϳϲϮͲϬϬͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗^/WƌŽĚƵĐĞƌ WĂĚ͗&ͲWĂĚ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗ĞĐĞŵďĞƌϱƚŚ͕ϮϬϮϭ ZŝŐ͗^Zϭ ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛Ě͍zĞƐ ĂƚĞZĞŐ͘ƉƉƌŽǀĂůZĞĐ͛ǀĚ͗ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗dŽŵ&ŽƵƚƐ WĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϭϵϳͲϬϳϰ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗ĂǀŝĚ'Žƌŵ ;ϵϬϳͿϳϳϳͲϴϯϯϯ;KͿ ;ϱϬϱͿϮϭϱͲϮϴϭϵ;DͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗dĂǇůŽƌtĞůůŵĂŶ ;ϵϬϳͿϳϳϳͲϴϰϰϵ;KͿ ;ϵϬϳͿϵϰϳͲϵϱϯϯ;DͿ ƵƌƌĞŶƚŽƚƚŽŵ,ŽůĞWƌĞƐƐƵƌĞ͗ Ϯ͕ϰϳϮƉƐŝΛϳ͕ϭϴϵ͛ds :W'ĂƵŐĞ͗ϭϭͬϯϬͬϮϬϮϭ;ϱͲĚĂǇ^/Ϳͮϲ͘ϳWW' DW^W͗ϭ͕ϳϱϮƉƐŝ 'ĂƐŽůƵŵŶ'ƌĂĚŝĞŶƚ;Ϭ͘ϭƉƐŝͬĨƚͿ DĂǆ/ŶĐůŝŶĂƚŝŽŶ ϲϬΣΛϱ͕ϬϬϬ͛D DĂǆŽŐůĞŐ͗ϯ͘ϱϭΣͬϭϬϬĨƚΛϱ͕ϳϬϬ͛D ƌŝĞĨtĞůů^ƵŵŵĂƌǇ͗ tĞůů&ͲϬϱǁĂƐĚƌŝůůĞĚďǇEĂďŽƌƐϮϮ͕ƉĞƌĨŽƌĂƚĞĚͬĨƌĂĐƚƵƌĞĚĂŶĚĐŽŵƉůĞƚĞĚďǇEĂďŽƌƐϰ^ŝŶDĂǇϭϵϵϳĂƐĂ <ƵƉĂƌƵŬϮͲƐĂŶĚƉƌŽĚƵĐĞƌ͘ZtK͛ƐƚŽƌĞƉůĂĐĞƚŚĞ^WŝŶϳͬϵϳ͕ϰͬϬϬ͕ϭϮͬϬϬΘϮͬϬϭĚƵĞƚŽĨƌĂĐƐĂŶĚ͘ƵƌŝŶŐƚŚĞ ^WƌĞƉůĂĐĞŵĞŶƚŝŶ:ƵŶĞϮϬϬϭ͕ϮϱϬͲŵŝĐƌŽŶƐĐƌĞĞŶƐǁĞƌĞŝŶƐƚĂůůĞĚƚŽƉƌĞǀĞŶƚĨƌĂĐƐĂŶĚƉƌŽĚƵĐƚŝŽŶ͘dŚŝƐ^WƌĂŶ ƵŶƚŝůĞĂƌůǇDĂǇϮϬϬϱǁŚĞŶŝƚƐŚƵƚĚŽǁŶĚƵĞƚŽĂŶĞůĞĐƚƌŝĐĂůĨĂŝůƵƌĞ͘ƵƌŝŶŐƚŚĞZtKŝŶůĂƚĞDĂǇϮϬϬϱƚŚĞ ƐĐƌĞĞŶƐǁĞƌĞƉƵůůĞĚĂŶĚƚŚĞϭΘϯƐĂŶĚƐǁĞƌĞƉĞƌĨŽƌĂƚĞĚ͘dŚĞ^WǁĂƐƌĞƉůĂĐĞĚŝŶ:ƵŶĞϮϬϭϮ͘dŚŝƐ^W ĨĂŝůĞĚŝŶEŽǀĞŵďĞƌϮϬϭϱĂŶĚǁĂƐ^/͘/ŶDĂƌĐŚϮϬϮϭƚŚĞ^WǁĂƐƉƵůůĞĚĂŶĚĂϰͲϭͬϮ͟:WŽŵƉůĞƚŝŽŶǁĂƐ ŝŶƐƚĂůůĞĚ͘ƉƌŝůϮϬϮϭDW&ͲϬϱǁĂƐdƐŝĚĞƚƌĂĐŬĞĚŝŶƚŽĂŶĞǁ<ƵƉĂƌƵŬ&ĂƵůƚďůŽĐŬ͘DW&ͲϬϱ:ĞƚĐŽŵƉůĞƚŝŽŶƌĂŶ ƵŶƚŝůĂŚŽůĞŝŶƚŚĞd'ĚĞǀĞůŽƉĞĚĂŶĚƚŚĞǁĞůůǁĂƐ^/ŽŶϭϭͲϮϱͲϮϬϮϭ͘ EŽƚĞƐZĞŐĂƌĚŝŶŐtĞůůďŽƌĞŽŶĚŝƚŝŽŶ x D/dͲ/WĂƐƐĞĚĂƚϯ͕ϱϬϬƉƐŝŐΛϴ͕ϯϭϲ͛DŽŶϯͬϭϰͬϮϬϮϭ͘ x dƵďŝŶŐůĞĂŬƐĐŽŶĨŝƌŵĞĚďĞƚǁĞĞŶϰ͕ϰϬϬ͛ʹϱ͕ϵϬϬ͛DŽŶϭϭͬϮϰͬϮϬϮϭǁŝƚŚƐůŝĐŬůŝŶĞŵĞŵŽƌǇůĞĂŬĚĞƚĞĐƚ͘ x EŽKĨĨƐĞƚ/ŶũĞĐƚŽƌƐŽŶůŝŶĞ KďũĞĐƚŝǀĞ͗ Ƶƚd'ĂďŽǀĞWĂĐŬĞƌ͕WKK,ƚŚĞϰͲϭͬϮ͟ŽŵƉůĞƚŝŽŶ͕Z/,ǁŝƚŚĂŶ^WŽŶϮͲϳͬϴ͟d' WƌĞͲZŝŐWƌŽĐĞĚƵƌĞ;EŽƐƵŶĚƌǇƌĞƋƵŝƌĞĚͿ͗ Ͳ>ŝŶĞ ϭ͘ Zh>ƵŶŝƚĂŶĚƉƌĞƐƐƵƌĞƚĞƐƚWƚŽϮϱϬƉƐŝůŽǁͬϮ͕ϱϬϬƉƐŝŚŝŐŚ͘ Ϯ͘ Z/,ĂŶĚĐŚĞŵŝĐĂůĐƵƚƚƵďŝŶŐĂƚϴ͕ϭϰϱ͛ŵĚ;Ϯ͛ďĞůŽǁƚŚĞƚŽƉĐŽůůĂƌŽĨƚŚĞϭϬ͛ƉƵƉũŽŝŶƚĂďŽǀĞƚŚĞ ƉĂĐŬĞƌ͕ƐĞĞƚƵďŝŶŐƚĂůůǇĚĂƚĞĚϬϯͬϭϮͬϮϭͿ͘ ϯ͘ WKK,ĂŶĚZ>ƵŶŝƚ͘ WƵŵƉŝŶŐΘtĞůů^ƵƉƉŽƌƚ ϰ͘ ůĞĂƌĂŶĚůĞǀĞůƉĂĚĂƌĞĂŝŶĨƌŽŶƚŽĨǁĞůů͘^ƉŽƚƌŝŐŵĂƚƐĂŶĚĐŽŶƚĂŝŶŵĞŶƚ͘ ϱ͘ ZǁĞůůŚŽƵƐĞĂŶĚĨůŽǁůŝŶĞƐ͘ůĞĂƌĂŶĚůĞǀĞůĂƌĞĂĂƌŽƵŶĚǁĞů ů͘ ϲ͘ Zh>ŝƚƚůĞZĞĚ^ĞƌǀŝĐĞƐ͘ZhƌĞǀĞƌƐĞŽƵƚƐŬŝĚĂŶĚϱϬϬďďůƌĞƚƵƌŶƐƚĂŶŬ͘ ZtKʹ:WƚŽ^W tĞůů͗DWh&ͲϬϱ ϳ͘ WƌĞƐƐƵƌĞƚĞƐƚůŝŶĞƐƚŽϯ͕ϬϬϬƉƐŝ͘ ϴ͘ ŝƌĐƵůĂƚĞĂƚůĞĂƐƚŽŶĞǁĞůůďŽƌĞǀŽůƵŵĞǁŝƚŚƉƌŽĚƵĐĞĚǁĂƚĞƌĚŽǁŶƚƵďŝŶŐ͕ƚĂŬŝŶŐƌĞƚƵƌŶƐƵƉĐĂƐŝŶŐ ƚŽϱϬϬďďůƌĞƚƵƌŶƐƚĂŶŬ͘ ϵ͘ ŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚ͘ŽŶƚĂĐƚƚŚĞŽƉĞƌĂƚŝŽŶƐĞŶŐŝŶĞĞƌŝĨĨƌĞĞǌĞƉƌŽƚĞĐƚŝŽŶŝƐŶĞĞĚĞĚĚĞƉĞŶĚŝŶŐŽŶ ^ZĂƌƌŝǀĂů͘ ϭϬ͘ Z>ŝƚƚůĞZĞĚ^ĞƌǀŝĐĞƐĂŶĚƌĞǀĞƌƐĞŽƵƚƐŬŝĚ͘ ϭϭ͘ ZhĐƌĂŶĞ͘^ĞƚWs͘EdƌĞĞ͘EhKW͘ZƌĂŶĞ͘ ϭϮ͘ EhKWŚŽƵƐĞ͘^ƉŽƚŵƵĚďŽĂƚ͘ ƌŝĞĨZtKWƌŽĐĞĚƵƌĞ͗ ϭϯ͘ D/Zh,ŝůĐŽƌƉ^ZηϭtKZŝŐ͕ĂŶĐŝůůĂƌǇĞƋƵŝƉŵĞŶƚĂŶĚůŝŶĞƐ͘ ϭϰ͘ ŚĞĐŬĨŽƌƉƌĞƐƐƵƌĞĂŶĚŝĨϬƉƐŝƉƵůůWs͘/ĨŶĞĞĚĞĚ͕ďůĞĞĚŽĨĨĂŶǇƌĞƐŝĚƵĂůƉƌĞƐƐƵƌĞŽĨĨƚƵďŝŶŐĂŶĚ ĐĂƐŝŶŐ͘/ĨŶĞĞĚĞĚ͕ŬŝůůǁĞůůǁͬƉƌŽĚƵĐĞĚǁĂƚĞƌƉƌŝŽƌƚŽƉƵůůŝŶŐWs͘^Ğƚdt͘ ϭϱ͘ dĞƐƚKWƚŽϮϱϬƉƐŝ>ŽǁͬϮ͕ϱϬϬƉƐŝ,ŝŐŚ͕ĂŶŶƵůĂƌƚŽϮϱϬƉƐŝ>ŽǁͬϮ͕ϱϬϬƉƐŝ,ŝŐŚ;ŚŽůĚĞĂĐŚ ƌĂŵͬǀĂůǀĞĂŶĚƚĞƐƚĨŽƌϱͲŵŝŶͿ͘ZĞĐŽƌĚĂĐĐƵŵƵůĂƚŽƌƉƌĞͲĐŚĂƌŐĞƉƌĞƐƐƵƌĞƐĂŶĚĐŚĂƌƚƚĞƐƚƐ͘ Ă͘ WĞƌĨŽƌŵdĞƐƚƉĞƌ^ZϭKWdĞƐƚWƌŽĐĞĚƵƌĞ ď͘ EŽƚŝĨǇK'ϮϰŚŽƵƌƐŝŶĂĚǀĂŶĐĞŽĨKWƚĞƐƚ͘ Đ͘ ŽŶĨŝƌŵƚĞƐƚƉƌĞƐƐƵƌĞƐƉĞƌƚŚĞ^ƵŶĚƌǇŽŶĚŝƚŝŽŶƐŽĨĂƉƉƌŽǀĂů͘ Ě͘ dĞƐƚsZƌĂŵƐŽŶϰͲϭͬϮ͟ĂŶĚϮͲϳͬϴ͟ƚĞƐƚũŽŝŶƚƐ͘ Ğ͘ ^ƵďŵŝƚƚŽK'ĐŽŵƉůĞƚĞĚϭϬͲϰϮϰĨŽƌŵǁŝƚŚŝŶϱĚĂǇƐŽĨKWƚĞƐƚ͘ ϭϲ͘ ŽŶƚŝŶŐĞŶĐǇ͗;/ĨƚŚĞƚƵďŝŶŐŚĂŶŐĞƌǁŽŶ͛ƚƉƌĞƐƐƵƌĞƚĞƐƚĚƵĞƚŽĞŝƚŚĞƌĂƉĞŶĞƚƌĂƚŽƌůĞĂŬŽƌƚŚĞWs ƉƌŽĨŝůĞŝƐĞƌŽĚĞĚĂŶĚͬŽƌĐŽƌƌŽĚĞĚĂŶĚWsĐĂŶŶŽƚďĞƐĞƚǁŝƚŚƚƌĞĞŽŶ͘Ϳ Ă͘ EŽƚŝĨǇKƉĞƌĂƚŝŽŶƐŶŐŝŶĞĞƌ;,ŝůĐŽƌƉͿ͕Dƌ͘DĞůZŝǆƐĞ;K'ͿĂŶĚDƌ͘:ŝŵZĞŐŐ;K'ͿǀŝĂ ĞŵĂŝůĞǆƉůĂŝŶŝŶŐƚŚĞǁĞůůŚĞĂĚƐŝƚƵĂƚŝŽŶƉƌŝŽƌƚŽƉĞƌĨŽƌŵŝŶŐƚŚĞƌŽůůŝŶŐƚĞƐƚ͘K'ŵĂǇĞůĞĐƚ ƚŽƐĞŶĚĂŶŝŶƐƉĞĐƚŽƌƚŽǁŝƚŶĞƐƐƚĞƐƚ͘ ď͘ tŝƚŚƐƚĂĐŬŽƵƚŽĨƚŚĞƚĞƐƚƉĂƚŚ͕ƚĞƐƚĐŚŽŬĞŵĂŶŝĨŽůĚƉĞƌƐƚĂŶĚĂƌĚƉƌŽĐĞĚƵƌĞ Đ͘ ŽŶĚƵĐƚĂƌŽůůŝŶŐƚĞƐƚ͗dĞƐƚƚŚĞƌĂŵƐĂŶĚĂŶŶƵůĂƌǁŝƚŚƚŚĞƉƵŵƉĐŽŶƚŝŶƵŝŶŐƚŽƉƵŵƉ͕;ŵŽŶŝƚŽƌ ƚŚĞƐƵƌĨĂĐĞĞƋƵŝƉŵĞŶƚĨŽƌůĞĂŬƐƚŽĞŶƐƵƌĞƚŚĂƚƚŚĞĨůƵŝĚŝƐŐŽŝŶŐĚŽǁŶͲŚŽůĞĂŶĚŶŽƚůĞĂŬŝŶŐ ĂŶǇǁŚĞƌĞĂƚƐƵƌĨĂĐĞ͘Ϳ Ě͘ ,ŽůĚĂĐŽŶƐƚĂŶƚƉƌĞƐƐƵƌĞŽŶƚŚĞĞƋƵŝƉŵĞŶƚĂŶĚŵŽŶŝƚŽƌƚŚĞĨůƵŝĚͬƉƵŵƉƌĂƚĞŝŶƚŽƚŚĞ ǁĞůů͘ZĞĐŽƌĚƚŚĞƉƵŵƉŝŶŐƌĂƚĞĂŶĚƉƌĞƐƐƵƌĞ͘ Ğ͘ KŶĐĞƚŚĞKWƌĂŵĂŶĚĂŶŶƵůĂƌƚĞƐƚƐĂƌĞĐŽŵƉůĞƚĞĚ͕ƚĞƐƚƚŚĞƌĞŵĂŝŶĚĞƌŽĨƚŚĞƐǇƐƚĞŵĨŽůůŽǁŝŶŐ ƚŚĞŶŽƌŵĂůƚĞƐƚƉƌŽĐĞĚƵƌĞ;ĨůŽŽƌǀĂůǀĞƐ͕ŐĂƐĚĞƚĞĐƚŝŽŶ͕ĞƚĐ͘Ϳ Ĩ͘ ZĞĐŽƌĚĂŶĚƌĞƉŽƌƚƚŚŝƐƚĞƐƚǁŝƚŚŶŽƚĞƐŝŶƚŚĞƌĞŵĂƌŬƐĐŽůƵŵŶƚŚĂƚƚŚĞƚƵďŝŶŐŚĂŶŐĞƌͬWs ƉƌŽĨŝůĞͬƉĞŶĞƚƌĂƚŽƌǁŽƵůĚŶ͛ƚŚŽůĚƉƌĞƐƐƵƌĞĂŶĚƌŽůůŝŶŐƚĞƐƚǁĂƐƉĞƌĨŽƌŵĞĚŽŶKWƋƵŝƉŵĞŶƚ ĂŶĚůŝƐƚŝƚĞŵƐ͕ƉƌĞƐƐƵƌĞƐĂŶĚƌĂƚĞƐ͘ ϭϳ͘ ůĞĞĚĂŶǇƉƌĞƐƐƵƌĞŽĨĨĐĂƐŝŶŐƚŽƚŚĞƌĞƚƵƌŶƐƚĂŶŬ͘WƵůůdt͘<ŝůůǁĞůůǁŝƚŚƉƌŽĚƵĐĞĚǁĂƚĞƌĂƐ ŶĞĞĚĞĚ͘ ϭϴ͘ DhůĂŶĚŝŶŐũŽŝŶƚŽƌƐƉĞĂƌĂŶĚWhŽŶƚŚĞƚƵďŝŶŐŚĂŶŐĞƌ͘ Ă͘ dŚĞWhǁĞŝŐŚƚŝƐĞƐƚŝŵĂƚĞĚĂƚϭϮϱ<ůďƐ͘ ď͘ /ĨŶĞĞĚĞĚ͕ĐŝƌĐƵůĂƚĞ;ůŽŶŐŽƌƌĞǀĞƌƐĞͿƉŝůůǁŝƚŚůƵďƌŝĐĂŶƚƉƌŝŽƌƚŽůĂǇŝŶŐĚŽǁŶƚŚĞƚƵďŝŶŐ ŚĂŶŐĞƌ͘ ϭϵ͘ ZĞĐŽǀĞƌƚŚĞƚƵďŝŶŐŚĂŶŐĞƌ͘ 1RWLI\$2*&&LIIOXLGGHQVLW\JUHDWHUWKDQSSJUHTXLUHGWRNLOOWKHZHOO ZtKʹ:WƚŽ^W tĞůů͗DWh&ͲϬϱ ŽŶƚŝŶŐĞŶĐǇ;/ĨĂƌŽůůŝŶŐƚĞƐƚǁĂƐĐŽŶĚƵĐƚĞĚͿ͗DhŶĞǁŚĂŶŐĞƌŽƌƚĞƐƚƉůƵŐƚŽƚŚĞĐŽŵƉůĞƚŝŽŶ ƚƵďŝŶŐ͘ZĞͲůĂŶĚŚĂŶŐĞƌ;ŽƌƚĞƐƚƉůƵŐͿŝŶƚƵďŝŶŐŚĞĂĚ͘dĞƐƚKWƉĞƌƐƚĂŶĚĂƌĚƉƌŽĐĞĚƵƌĞ͘ ϮϬ͘ WKK,ĂŶĚůĂǇĚŽǁŶƚŚĞϰͲϭͬϮ͟ƚƵďŝŶŐ;ϭϬϱĐĂŶŶŽŶĐůĂŵƉƐͿ͘ůůƚƵďƵůĂƌƐƌĞĐŽǀĞƌĞĚǁŝůůďĞũƵŶŬĞĚ͕ /ŶƐƉĞĐƚƚŚĞƉƌŽĨŝůĞ͕ĐĂŶŶŽŶĐůĂŵƉƐ͕ƐůŝĚŝŶŐƐůĞĞǀĞĂŶĚŐĂƵŐĞƐĨŽƌŝŶǀĞŶƚŽƌǇ͘ Ϯϭ͘ WhŶĞǁ^WĂŶĚZ/,ŽŶϮͲϳͬϴ͟ϲ͘ϱη>ͲϴϬƚƵďŝŶŐ͘ŚĞĐŬĞůĞĐƚƌŝĐĂůĐŽŶŶĞĐƚŝŽŶƐĞǀĞƌǇϮ͕ϬϬϬ͛ Ă͘ ĂƐĞŽĨ^WĂƚцϴ͕ϭϬϬ͛D ď͘ ϭũŽŝŶƚƐŽĨϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐ Đ͘ ϮͲϳͬϴ͟yE;Ϯ͘ϮϬϱ͟EŽͲ'ŽͿEŝƉƉůĞ Ě͘ ϭũŽŝŶƚŽĨϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐ Ğ͘ >ŽǁĞƌϮͲϳͬϴ͟ǆϭ͟^ŝĚĞͲƉŽĐŬĞƚ'>DǁŝƚŚƵŵŵǇ'>s Ĩ͘ DƵůƚŝƉůĞũŽŝŶƚƐϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐ Ő͘ hƉƉĞƌϮͲϳͬϴ͟ǆϭ͟^ŝĚĞͲƉŽĐŬĞƚ'>DΛцϮϬϬ͛DǁŝƚŚϬ͘Ϯϱ͟Ks Ś͘ цϱũŽŝŶƚƐϮͲϳͬϴ͕͟ϲ͘ϱη͕>ͲϴϬ͕hϴƌĚƚƵďŝŶŐ ϮϮ͘ >ĂŶĚƚƵďŝŶŐŚĂŶŐĞƌ;ĂƵƚŝŽŶŶŽƚƚŽĂŵĂŐĞĂďůĞǁŚŝůĞůĂŶĚŝŶŐƚŚĞŚĂŶŐĞƌͿ͘>ĂǇĚŽǁŶůĂŶĚŝŶŐ ũŽŝŶƚ͘EŽƚĞWh;WŝĐŬhƉͿĂŶĚ^K;^ůĂĐŬKĨĨͿǁĞŝŐŚƚƐŽŶƚĂůůǇ͘ Ϯϯ͘ ^ĞƚWs͘ WŽƐƚͲZŝŐWƌŽĐĞĚƵƌĞ͗ tĞůů^ƵƉƉŽƌƚ ϭ͘ ZŵƵĚďŽĂƚ͘ZKWŚŽƵƐĞ͘DŽǀĞƚŽŶĞǆƚǁĞůůůŽĐĂƚŝŽŶ͘ Ϯ͘ ZhĐƌĂŶĞ͘EKW͘ ϯ͘ EhĞǆŝƐƚŝŶŐϯͲϭͬϴ͟ϱ͕ϬϬϬηƚƌĞĞͬĂĚĂƉƚĞƌĨůĂŶŐĞ͘dĞƐƚƚƵďŝŶŐŚĂŶŐĞƌǀŽŝĚƚŽϱϬϬƉƐŝůŽǁͬϱ͕ϬϬϬƉƐŝ ŚŝŐŚ͘WƵůůWs͘ ϰ͘ ZĐƌĂŶĞ͘DŽǀĞϱϬϬďďůƌĞƚƵƌŶƐƚĂŶŬĂŶĚƌŝŐŵĂƚƐƚŽŶĞǆƚǁĞůůůŽĐĂƚŝŽŶ͘ ϱ͘ ZĞƉůĂĐĞŐĂƵŐĞ;ƐͿŝĨƌĞŵŽǀĞĚ͘ ϲ͘ dƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶ͘ZhǁĞůůŚŽƵƐĞĂŶĚĨůŽǁůŝŶĞƐ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƐͲďƵŝůƚ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ KW^ĐŚĞŵĂƚŝĐ ϰ͘ ϰ͘ϱ͟dƵďŝŶŐdĂůůǇ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚǇ͗d&ϭϭͬϯϬͬϮϬϮϭ ^,Dd/ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DW&ͲϬϱͬ>ϭͬ>ϭͲϬϭ >ĂƐƚŽŵƉůĞƚĞĚ͗ϯͬϭϮͬϮϬϮϭ Wd͗ϭϵϳͲϬϳϰͬϮϮϭͲϬϭϰͬϮϮϭͲϬϭϱ ´;26ORWWHG WR6ROLG/LQHU# ¶)/ :KLSVWRFN /VHWLQ ´ #¶)/ 7' ¶0'¶79' 3%7' ¶0'¶79' )/ 7' ¶0'¶79' 3%7' ¶0'¶79' dсϴ͕ϴϵϱ͛;DͿͬdсϳ͕ϰϱϵ͛;dsͿ ϮϬ´ 7RSRI :KLSVWRFN# ¶ KƌŝŐ͘<ůĞǀ͗͘ϰϭ͘ϯ͛ͬ'>ůĞǀ͗͘ϭϮ͘ϯ͛ ϳ͟ ´(6 &HPHQWHU # 0' ϵͲϱͬϴ͟ .83$ 6DQGV 7RSRI ´ /LQHU# ¶ /LQHUWRS 3DFNHU #¶ Wdсϴ͕ϳϵϳ͛;DͿͬWdсϳ͕ϯϲϭ͛;dsͿ 7RSRI´ /LQHU# ¶ .83$6DQGV .83$6DQGV 7ZR´ [¶0DUNHU -RLQWVI¶± ¶5.% ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϭ͘ϭͬ,ͲϰϬͬEͬ Eͬ ^ƵƌĨĂĐĞ ϭϭϮΖ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬƚƌĐ͘ ϴ͘ϲϳϵ ^ƵƌĨĂĐĞ ϱ͕ϱϳϬ͛ ϳΗ WƌŽĚƵĐƚŝŽŶ Ϯϲͬ>ͲϴϬͬƚĐDŽĚ ϲ͘Ϯϳϲ ^ƵƌĨĂĐĞ ϴ͕ϴϴϬ͛ >ϭ͗ϯͲϭͬϰ͟ ^ŽůŝĚ>ŝŶĞƌ ϲ͘ϲͬ>ͲϴϬͬd// ϴ͕ϯϭϬ͛ ϵ͕ϲϵϬ͛ >ϭͲϬϭ͗ϮͲϯͬϴ͟ ^ŽůŝĚͬ^ůŽƚƚĞĚ>ŝŶĞƌ ϰ͘ϳͬ>ͲϴϬͬ^d>Θ,ϱϭϭ ϴ͕ϯϭϴ͛ ϭϭ͕ϮϭϬ͛ dh/E'd/> ϰͲϭͬϮΗ dƵďŝŶŐ ϭϮ͘ϲͬ>ͲϴϬͬdyW ϯ͘ϵϱϴ͟ ^ƵƌĨ ϴ͕ϯϭϲ͛ KWE,K>ͬDEdd/> ϮϰΗ ŵƚǁͬϮϱϬƐŬƐŽĨƌĐƚŝĐƐĞƚ/;ƉƉƌŽǆ͘Ϳ ϭϮͲϭͬϰΗ ŵƚǁͬϭ͕ϰϯϲƐŬƐW&͚͕͛ϲϬϬƐǆůĂƐƐ͚'͛ ϴͲϭͬϮ͟ ŵƚǁͬϮϱϬƐŬƐůĂƐƐ͚'͛ ϰͲϭͬϰ͟ǆϯ͟ hŶĐĞŵĞŶƚĞĚ^ŽůŝĚͬ^ůŽƚƚĞĚ>ŝŶĞƌ;DWh&ͲϬϱ>ϭΘ>ϭͲϬϭͿ t>>/E>/Ed/KEd/> <KWΛϮ͕ϬϬϬ͛ DĂǆ,ŽůĞŶŐůĞсϲϭĚĞŐ͘Λϱ͕ϮϮϬ͛ &ͲϬϱ>ϭǁŝŶĚŽǁΛϴ͕ϯϳϰ͕͛&ͲϬϱ>ϭͲϬϭǁŝŶĚŽǁΛϵ͕ϯϳϴ͛ dZΘt>>, dƌĞĞ ĂŵĞƌŽŶϰͲϭͬϭϲ͟ϱD tĞůůŚĞĂĚ ϭϭ͟ǆϭϭ͟ϱ<&D'ĞŶϱ͕ǁͬϰͲϭͬϮ͟ƚůĂƐƌĂĚĨŽƌĚŚŐƌ͘ dďŐ,ĂŶŐĞƌ ϰͲϭͬϮ͟dͲϭͲD^ϭϭǆϰͲϭͬϮ͟ƚůĂƐƌĂĚĨŽƌĚ dͲ//͕ϭϮ͘ϲηƚŽƉΘďŽƚƚŽŵ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϮϳϲϮͲϬϬͲϬϬͬϲϬͲϬϬͬϲϭͲϬϬ 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Haakinson Cc: Chad Helgeson; Tom Fouts Subject: RE: [EXTERNAL] RE: MPU F-05 (PTD 221-014) SSSV Variance Request David —Thank you for the call and information. Hilcorp is approved to substitute the Weatherford PB SSCSV for the Halliburton Storm Choke K -valve. Jim Regg Supervisor, Inspections AOGCC 333 W. Th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: David Gorm <dgorm@hilcorp.com> Sent: Friday, June 11, 20211:41 PM To: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>; David Haakinson <dhaakinson@hilcorp.com> Cc: Chad Helgeson <chelgeson@hilcorp.com>; Tom Fouts <tfouts@hilcorp.com>; Regg, James B (CED) <jim.regg@alaska.gov> Subject: RE: [EXTERNAL] RE: MPU F-05 (PTD 221-014) SSSV Variance Request Mel/Regg, The Halliburton "K -Valve" SSSV we were intending to utilize for F-05 needs a re -dress kit requesting to utilize Weatherfords equivalent "PB" SSSV. Please find attached the data be utilizing the same process taking the down hole pressure gauge data to guide or d valve. Thanks, David Gorm Operations Engineer Hilcorp Alaska Office: 907-777-8333 Cell: 505-215-2819 From: Rixse, Melvin G (CED) <melvin. Sent: Friday, June 11, 202110:43 AM To: David Haakinson <dhaakinson@h Cc: Chad Helgeson <chelaeson@hilco ill be delayed. Hilcorp is eet for the "PB" SSSV. We will pressure settings on the "PB" >; David Gorm <dsorm@hilcorp.com>; Tom Fouts <tfouts@hilcorp.com>; Regg, James B (CED) <'im.re a z(ska. ov> Subject: [EXTERNAL] RE: MPU 05 (PTD 221-014) SSSV Variance Request MPUI � r:�5 Regg, James B (CED) �M ig70X40 From: David Gorm <dgorm@hilcorp.com> Sent: Friday, June 11, 2021 1:41 PM ) 71 611,(Lo Z( To: Rixse, Melvin G (CED); David Haakinson Cc: Chad Helgeson; Tom Fouts; Regg, James B (CED) Subject: RE: [EXTERNAL] RE: MPU F-05 (PTD 221-014) SSSV Variance Request Attachments: W i rel i ne-Retrievable-Su bsurface-Control led -Su bsu rface-Safety-Va Ive-Models-P B -a nd- HP-PB.pdf Mel/Regg, The Halliburton "K -Valve" SSSV we were intending to utilize for F-05 needs a re -dress kit and will be delayed. Hilcorp is requesting to utilize Weatherfords equivalent "PB" SSSV. Please find attached the data sheet for the "PB" SSSV. We will be utilizing the same process taking the down hole pressure gauge data to guide or dome pressure settings on the "PB" valve. Thanks, David Gorm Operations Engineer Hilcorp Alaska Office: 907-777-8333 Cell: 505-215-2819 From: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Sent: Friday, June 11, 202110:43 AM To: David Haakinson <dhaakinson@hilcorp.com> Cc: Chad Helgeson <chelgeson@hilcorp.com>; David Gorm <dgorm@hilcorp.com>; Tom Fouts <tfouts@hilcorp.com>; Regg, James B (CED) <jim.regg@alaska.gov> Subject: [EXTERNAL] RE: MPU F-05 (PTD 221-014) SSSV Variance Request David, Hilcorp is approved to proceed on MPU F-05 (PTD221-014) SSSV operations as you describe below. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231) or (Melvin. Rixse@alaska.gov). cc. Chad, David, Tom, Jim Regg From: David Haakinson <dhaal<inson@hilcorp.com> Sent: Thursday, June 10, 20214:32 PM To: Rixse, Melvin G (CED) <melvin.rixse@alaska.aov> Cc: Chad Helgeson <cheleeson@hilcorp.com>; David Gorm <deorm@hilcorp.com>; Tom Fouts <tfouts@hilcorp.com> Subject: MPU F-05 (PTD 221-014) SSSV Variance Request Mel, Hilcorp Alaska requests approval to install a pressure controlled 'Halliburton K' subsurface safety -valve as a variance to 20 AAC 25.265 in producer MPU F-05. The use of the Halliburton K -Valve has been a proven option on the North Slope and utilized in similar situations where surface control is not possible. Downhole gauges are planned to be removed from the well on Friday June 111h for design application with a planned set date of Saturday June 12th, pending your approval. Information for the valve design will be as followed: • Valve Specification: 4-1/2" Halliburton 22KX14 Valve. A data sheet is attached and Halliburton will be setting the Nitrogen bellows pressure. o This is a normally closed valve closes when the flowing pressure decreases below the design set pressure. • Fluid Flow Composition: o 4250 BLPD • 3180 BWPD power fluid 1070 BOPD produced fluid o 428 mscf/d • Design Pressures: Surface Pressure Shut in = 375 psi trip pressure (25 psi of backpressure) o Downhole pressure and temperature gauge data will be used to properly design the dome pressure. o Note the final set pressures will be determined after pulling of the downhole gauges. Design Model: Halliburton software. The nitrogen bellows set point will be verified internally by calculation of nitrogen bellows using real -gas law. • Procedure: o Install the K -valve in the X -Nipple at 2,058' MD (2,058' TVD). o Confirm closure at surface pressure set point. RDMO Slickline. o Pump open K -valve and bring online after successful test. o Follow up with AOGCC witnessed SSSV test after restarting F-05 production. Please let me know if you have any questions. I will be out of service by -1200 hours on Friday 6/11, and thus I've copied Chad and David G. if anything additional is needed. Thanks for your help today and I appreciate your time to meet with us. David Haakinson Operations Lngineer I North Slope Asset't-eam Hilcorp Alaska, LLC Office: (407) 777-8343 1 Cell: (307) 660-4999 dhaakinson:ii,' hiiIcc�.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The Information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the senders phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Run 4-1/2" completion Hilcorp Alaska Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8,895 feet N/A feet true vertical 7,459 feet N/A feet Effective Depth measured 8,797 feet 8,154 feet true vertical 7,361 feet 6,718 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 / TXP 8,316' 6,880' Packers and SSSV (type, measured and true vertical depth)4.5"x7" Premier Prod N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse 470psi 3,090psi Burst 1,490psi 5,750psi 7,240psi 777-8333 20" 9-5/8" 7" 4,576' 7,444' 5,410psi Casing Structural Length 112' 5,570' 8,880' Conductor Surface MILNE PT UNIT F-05 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 Casing Pressure Tubing Pressure 0 N/A measured 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 0 Authorized Signature with date: Authorized Name: David Gorm dgorm@hilcorp.com 150 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 197-074 50-029-22762-00-00 Plugs ADL0025509 & ADL0388235 5. Permit to Drill Number: MILNE POINT / KUPARUK RIVER OIL Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 00 0 Oil-Bbl measured true vertical Packer Size N/A WINJ WAG 0 Water-Bbl MD 112' 5,570' 8,880' TVD 112' Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 1:20 pm, Jun 04, 2021 Chad Helgeson (1517) 2021.06.04 13:00:07 - 08'00' DSR-6/7/21 SFD 6/17/2021RBDMS HEW 6/4/2021 MGR30JUL2021 _____________________________________________________________________________________ Revised By: TDF 6/5/2021 SCHEMATIC Milne Point Unit Well: MP F-05 Last Completed: 3/12/2021 PTD: 197-074 TD =8,895’ (MD) / TD = 7,459’(TVD) 20” Orig. KB Elev.: 29’/ GL Elev.: 12.3’ 7” 2 4 6 7 8 9 9-5/8” ES Cementer @ 2,005 MD 9-5/8” 1 3 KUP A3 Sands PBTD =8,797’(MD) / PBTD = 7,361’(TVD) 5 KUP A2 Sands KUP A1 Sands Two 7” x 21’ Marker Joints f/ 8,273’ – 8,314’ RKB Top of Whipstock @ 8,365’ Top of Window @ 8,374’, Bottom @ 8,379’ 1111 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surf 112' 9-5/8" Surface 40 / L-80 / Btrc. 8.679 Surf 5,570’ 7" Production 26 / L-80 / Btc Mod 6.276 Surface 8,880’ TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / TXP 3.958” Surf 8,316’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A3 Sands 8,460’ 8,472’ 7,024’ 7,036’ 12 5/31/2005 Open Kup. A2 Sands 8,478’ 8,498’ 7,042’ 7,062’ 20 5/18/1997 Open Kup. A1 Sands 8,503’ 8,523’ 7,067’ 7,087’ 20 5/31/2005 Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I (Approx.) in 24” Hole 9-5/8" Cmt w/ 1,436 sks PF “E”, 600 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 250 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 2,000’ Max Hole Angle = 61 deg. @ 5,220’ Hole Angle through perforations = > 1 deg. TREE & WELLHEAD Tree Cameron 4-1/16” 5M Wellhead 11” x 11” 5K FMC Gen 5A, w/ 4-1/2” Atlas Bradford hgr. Tbg Hanger 4-1/2” TC-1A-EMS 11 x 4-1/2” Atlas Bradford TC-II, 12.6# top & bottom GENERAL WELL INFO API: 50-029-22762-00-00 Drilled and Cased by Nabors 22E - 5/7/1997 1st Perforated w/ Wireline – 5/18/1997 ESP Completion #1 w/ Nabors 4-ES – 5/24/1997 ESP RWO w/ Nabors 4-ES – 7/99, 4/00, 12/00 & 2/01 ESP RWO, Add Screens w/ Nabors 4-ES – 6/15/2001 ESP RWO, Remove Screens & Add Perfs w/ Nabors 4-ES – 5/30/2005 ESP RWO w/ Doyon 16 – 6/28/2012 Run Completion w/ Doyon 14 – 3/12/2021 JEWELRY DETAIL No Depth Item 1 30’ 4-1/2” Tubing Hanger 2 2,058’ X Nipple, ID = 3.813” 3 8,079’ Gauge Carrier, Baker injection mandrel 4 8,086’ Sliding Sleeve, 3.813” Seal Bore ID, Open DN 5 8,091’ Baker Ported Pressure Sub 6 8,154’ 4-/1/2” x 7” Baker Premier Production Packer 7 8,225’ X Nipple, ID = 3.813” 8 8,276’ WLEG, bottom at 8,316’ Well Name Rig API Number Well Permit Number Start Date End Date MP F-05 Doyon 14 50-029-22762-00-00 197074 3/7/2021 5/4/2021 No operations to report. 3/6/2021 - Saturday Jack up rig, remove shims. Pull Rig off F-81. Move Rig down the pad and around Well row staging on east side of pad while wait for BPV to be installed in F-05. Wellhead support crew install BPV in F-05. Position rig on matting boards and back over well. Well support remove ladder from adjacent wellhouse to allow room for rig to center over well. Spot rig over F-05 and shim level. Skid rig floor into drilling position. Rig up and work on acceptance checklist. Hook up power to top drive. R/U rig floor steam, water, air and high pressure mud lines. Prepare mud pits for fluid and load w/ 11.0 ppg NaCl/NaBr brine. Spot rock washer and fuel trailer and support buildings. Lower stairways and install landings. Spot cuttings tank and build containment. Rig up hydraulic lubricator and well support crew pull BPV. Finish acceptance checklist. R/U 2" hardline and hoses to flow back tank. Blow air and steam through lines to tank. Fill lines with fresh water and pressure test. Pressure test to 4000 PSI - good. Blow down lines. Rig Accepted at 22:00. Initial 1300 PSI on Tbg and 1350 PSI on IA. Line up and pump 270 bbls hot H2O down tubing, returns from IA to kill tank, holding ~200 psi back pressure. ICP = 1500 psi @ 2.5 BPM, FCP = 1020 psi @ 2.5 BPM. Gas returns first 20 bbls pumped then straight crude oil. See trace diesel in oil at 165 bbls pumped and straight diesel with 235 bbls pumped. Seeing diesel contaminated H2O back when shut down. 232 bbls returned. Shut in and monitor well while line up hi vis spacer and 11.0 ppg KWF. Initial SITP = 680 psi stabilize at 820 psi. Initial SICP @ 725 psi, stabilize at 850 psi. Blow down lines. Mobilize H20/soap vac truck to kill tank and empty same. Line up pumps to pill pit for 11.0 ppg hi vis brine spacer. 3/7/2021 - Sunday Rig down and blow down high pressure lines and squeeze manifold in cellar. Circulate soap pill through surface lines and blow down. Rig down and move fuel trailer, rockwasher, cuttings box, mudman shack & 5 star building. Prep rig floor for skidding.,PJSM and pre-skid rig floor checklist. Skid rig floor into moving position. 3/8/2021 - Monday 3/5/2021 - Friday No operations to report. 3/3/2021 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 3/4/2021 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP F-05 Doyon 14 50-029-22762-00-00 197074 3/7/2021 5/4/2021 Hilcorp Alaska, LLC Weekly Operations Summary Pump 30 bbls 11.0 ppg hi vis brine spacer down Tbg, returns from IA to kill tank. Chase spacer with 70 bbls, 11.0 ppg NaCl/NaBr Brine, hold 200 psi backpressure. ICP = 1650 @ 3 BPM FCP = 780 @ 3 BPM. Shut in annulus and bullhead 15 bbls 11.0 ppg KWF @ 1 BPM – 1200 psi, spotting KWF from empty pocket in GLM at 7996’ to bottom of perfs at 8523’. Open IA choke and continue pumping 11.0 ppg KWF stage up to 3 BPM.,ICP @ 1150 / FCP 810 psi. See sweep interface back with 290 bbls KWF pumped. 10.9 ppg brine returns with 430 bbls KWF pumped 387 bbls returned to kill tank. Shut down and monitor pressures for 30 min. SITP @ 180 psi, drop to 120 psi, SICP @ 200 psi drop to 150 psi. Bleed off 1 bbls increments and monitor between. With 2 bbls bled off, both Tbg & IA stabilize @ 50 psi. Rig up return line from IA to choke manifold / gas buster and to pits. Test choke lines 250/4000 psi. Circulate STS volume down tubing, returns through full open super choke / gas buster and to mud pits. 3 BPM, ICP-650 psi, FCP-800 psi. Brine wt 10.95 ppg in/out. 15 BPH loss rate for 18 total bbls loss while circulating. Monitor pressures 30 minutes. SITP @ 100 psi drop to 75 psi, SICP @ 150 psi drop to 70 psi. Equalize tubing and I/A & bleed pressure off through choke. Initial breath back at 1.5 BPH slowing down steadily and ceasing after 1.5 hrs. Blow down and rig down circulating lines. Install BPV. Bleed off void and Nipple down Tree. Clean and inspect hanger threads - good. Dummy run 3” LH Acme x 2-7/8” EUE 8rd XO in hanger. Install test dart in BPV. Function lockdowns, verify free – good. Nipple up BOP, M/U kill line, energize accumulator. Call out rig welder, cut 1.68’ off riser to compensate for added 11” x 7” adapter flange. Install riser and mousehole. Obtain RKB measurements. Function BOP Rams, Rig up test equipment. Install 4-1/2" test joint and R/U test equipment. Fill stack with water. Lower air boot leaking on riser. Suck stack down below lower air boot. Change out both top and bottom riser air boots. Fill stack with water. Perform shell test: 250/3500 psi -good. Test BOPs as per AOGCC, PTC & Hilcorp requirements. AOGCC notified of testing at 18:36 on 06 March 2021. AOGCC rep. Lou Laubenstein waived the right to witness test at 17:54 on 08 March 2021. All test performed with fresh water against a test dart installed in BPV. Test held for 5 min each and charted. Annular tested to 250 PSI / 2500 PSI & all other tests to 250 PSI / 4000 PSI.,1) Upper 2-7/8" x 5" VBR on 4-1/2" test joint, choke valves 1,12, 13, 14, kill line Demco & upper IBOP. Testing continue onto next report. 3/9/2021 - Tuesday Well Name Rig API Number Well Permit Number Start Date End Date MP F-05 Doyon 14 50-029-22762-00-00 197074 3/7/2021 5/4/2021 3/10/2021 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Continue to test BOPE as per AOGCC, PTC & Hilcorp requirements. All test performed with fresh water against a test dart installed in BPV. Test held for 5 min each and charted. Annular tested to 250 PSI / 2500 PSI & all other tests to 250 PSI / 4000 PSI. 2) Choke valves 9, 11, HCR kill & lower IBOP, 3) Choke valves 5, 8, 10, manual kill, 4) Choke valves 4, 6, 7,5) Choke valve 2, 6) HCR choke, 7) Lower 2-7/8" x 5" VBR on 4-1/2" test joint, 8) Annular on 2-7/8" test joint, 9) Upper 2-7/8" x 5" VBR on 2-7/8" test joint, Manual choke 3-1/2” Dart Valve, 10) Lower 2-7/8" x 5" VBR on 2-7/8" test joint 3-1/2" FOSV #1,11) Blind Rams, Choke valve 3, 3-1/2" FOSV #2, 12) Hydraulic choke A, 13) Manual choke B. Perform accumulator test, 3100 psi system pressure, 16 psi after closure, 200 psi attained in 38 sec, full pressure in 195 sec. 6 N2 bottle avg = 2050 psi. Rig electrician test rig gas alarms, verify PVT system. R/D test equipment, Blow down lines and rig down test equipment. Suck out stack, Remove test dart and BPV, M/U 3" LH ACME XO to 2-7/8" EUE landing joint, XO, FOSV, XO and 2-7/8" pup joint. Engage Hanger, BOLDS. P/U and unseat hanger with 95K (40K block weight). Fill hole - 10 bbls to fill. Hoist hanger to the rig floor with 90K PU.,L/D hanger, landing joint, XOs and FOSV. POOH L/D 2-7/8" 6.5# EUE L-80 tubing from 8253' to 7959'. Hold Kick while tripping drill with Rig crew. Losses @ 3 BPH, Monitor well via trip tank – 2 BPH static loss rate. Mobilize Baker TST 3 retrievable packer to Rig floor. P/U 7'' Baker retrievable storm packer and XOs. 85k PU / 75k SO. RIH with 1 joint 4-1/2'' Tubing, & set storm packer with center of elements @ 59’. Flood lines, close close annular, line up down tubing and backside. pressure up and test packer to 1500 psi,10 min charted, good test. Blow down lines and drain stack. Nipple down BOP stack, kill line, bell nipple, BOP anchors, set on pedestal. Install new tubing spool & nipple up BOP stack. Torque 2 sets flange bolts, re-install riser, anchors and kill line. Wellhead Rep test packoff void 500/5000 psi 10 min. – good test,Rig up test equipment. Set test plug, flood lines and stack with fresh H2O. Close blinds and test breaks to 250 / 4000 psi 5 min charted. – good test. Bleed down, pull test plug.,Make up XO, FOSV and pup to jt of 4-1/2” tubing. Engage storm packer and open equalizing valve to closed FOSV. Open FOSV and observe a vac. Release storm packer and break down XO and FOSV. 1.5 bbls to fill hole. Pull storm packer to rig floor and lay down same. 85k PU / 75k SO, 2 BPH static loss rate. 3/11/2021 - Thursday POOH f/ 7959' t/ 7869' laying down 3x jts 2-7/8” tubing to shed. Rig up Centrilift equipment and pull ESP cable to spooling unit. 2 BPH losses. POOH laying down 2-7/8” 6.5# EUE L-80 tubing f/ 7869' t/ 64’. Total of 257 jts pulled. 238 cannon clamps, 2 half clamps, 5 protectolizers & 3 flat guards. ESP Cable Burned/Blown out 5’ below X nipple. 2 BPH losses. Lay down ESP assembly. BPV debris found in top of pump assembly. Top seal wet, bottom seal & motor has discolored oil. Shaft in gas separator broken. 24 bbls total loss while pulling 2-7/8" ESP string. Clear floor & Clean Rig floor. Lay down 2- 7/8” handling equipment, power tongs and used cannon clamps. Mobilize 4-1/2” equipment to Rig floor and rig up. Static losses at 1 BPH, P/U WLEG shoe jt, jt 4.5” tubing, X nipple w/ RHC plug, jt 4.5” tubing, Baker Premier Packer and jt 4.5” tubing to 212’. M/U ported pressure sub, HES X line Sliding sleeve, XO’s & injection mandrel assembly. Make up TEC wire to gauges and perform initial test - good. RIH w/ 4.5" 12.6# L-80 TXP completion string f/ 245' to 3365'. Install 1 cannon clamp first 10 connections then one every other connection. Test tec wire every 1000'. Torque to optimum @ 6170 ft/lbs with Doyon double stack tongs. PU 70K, SO 75K. 1 BPH losses. Well Name Rig API Number Well Permit Number Start Date End Date MP F-05 Doyon 14 50-029-22762-00-00 197074 3/7/2021 5/4/2021 Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. Bleed down tubing to 2000 psi. Pressure up to 3500 psi with test pump down 7" x 4-1/2" IA. Hold 30 min on chart. - Good test. Bleed IA to 0, Bleed tubing to 1000 psi and shut in. Rig down and blow down high pressure lines and squeeze manifold in cellar. Secure Tree. Circulate soap pill through surface lines and blow down. Clean pits. R&R flanges on old tree as per WellHead Rep. Rig down and move fuel trailer, mudman shack & 5 star building. Clear and clean cellar area. Remove ESP drain trunk and rig down high pressure lines on rig floor. Blow down service lines to rig floor and prep to skid floor. Rig down and move rockwasher & cuttings box. Skid rig floor into moving position. Rig released at 12:00 3/13/2021 - Saturday Rig up slickline. WELL S/I ON ARRIVAL, OPEN PERMIT W/PAD-OP, PT PCE 250L/2,500H. PULLED BALL AND ROD FROM @ 8,232' SLM. PULLED RHC PLUG BODY FROM 8,238' SLM. WELL SHUT IN ON DEPARTURE , DSO NOTIFIED. 3/16/2021 - Tuesday 3/14/2021 - Sunday No operations to report. 3/15/2021 - Monday 3/12/2021 - Friday Continue RIH p/up 4.5" 12.6# L-80 TXP completion string as per tally f/ 3365' to hanger. Installing cannon clamp every other connections and Test tec wire every 1000'. Torque to optimum @ 6170 ft/lbs with Doyon double stack tongs. PU 122K, SO 107K, blocks @ 60k. 1 BPH losses. Dress hanger w/ Tec wire while draining stack and blowing dn lines / RIH and land hanger w/ 67k w/ mule shoe @ 8316' . Top of Packer @ 8154' / RILDS / Back out landing jt and install BPV, Nipple down BOPE stack and set on moving stump. Install test plug in BPV. N/U tree and adaptor flange. Terminate TEC wire to tubing head adapter. SimOps: Haul off excess brine and cleaning pits,Test void to 500/5000 psi for 5/10 min - Good. R/U & test tree to 250/5000 psi - Good. Centrilift take final readings, Pt 3790.29 psi, Pa 3790.28 psi. Tt 160.4°, Ta 160.4°,Pull BPV. M/U lubricator extension to Tree with Ball and Rod installed on shut Swab Valve. Rig up high pressure lines and squeeze manifold. PT lines t/ 4000 psi. Line up on 7'' X 4-1/2” IA and reverse circulate 107 bbls seawater with 1% Concor 303 corrosion inhibiter. ICP 420 psi @ 3 BPM, FCP 960 psi @ 3 BPM. Blow down lines and pumps. Pump 47 bbl diesel freeze protect down IA, ICP 810 psi @ 2 BPM, FCP 1230 psi @ 2 BPM. Shut in IA. Bullhead 37 bbl diesel freeze protect down tubing. ICP 260 psi @ 1 BPM, FCP 1180 psi @ 0.5 BPM,Open swab valve and drop 1.875” ball and rod, hear possible confirmation of ball/rod fall. Let fall on seat for 15 min. Line up test pump to squeeze manifold. Attempt to pressure up on tubing with no success. Line up to mud pump and pump 15 bbls diesel from truck @ 2 BPM with no pressure increase. Shut master valve and bleed pressure in tree down. Open Swab valve and hear definite confirmation of ball/rod contact. Open master valve and both hear and feel ball/rod drop. Let fall 15 min and pressure up to 4700 psi down tubing setting packer, IA pressure rise from 1100 psi to 1400 psi and stabilize. Hold for 10 min. - Good. Observed 1st shear @ 2600 psi. Bleed down tubing to 1000 psi. Bleed IA pressure down to 0. Pressure up to 3500 psi with test pump down tubing. Hold 30 min on chart. - Good tubing test. Well Name Rig API Number Well Permit Number Start Date End Date MP F-05 Slickline 50-029-22762-00-00 197-074 3/7/2021 5/4/2021 3/26/2021 - Friday No operations to report. 3/24/2021 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 3/25/2021 - Thursday WELL S/I ON ARRIVAL, OPEN PERMIT W/PAD-OP, PT PCE 250L/1500H. DRIFT TBG WITH 20'x3.70" DUMMY WHIPSTOCK TO 8,500' SLM (no restrictions) WHIPSTOCK TARGET DEPTH 8,405' MD. RDMO, CLOSE PERMIT W/PAD-OP. No operations to report. No operations to report. 3/27/2021 - Saturday No operations to report. 3/30/2021 - Tuesday 3/28/2021 - Sunday No operations to report. 3/29/2021 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MPU F-05L1 & L1-01 CDR2 50-029-22632-60 & 61-00 221-014 & 211-015 3/7/2021 5/4/2021 No operations to report 5/1/2021 - Saturday Continue RIH with Nozzle BHA taking returns to the TT Tag at 8725', PU to 8700' and displace well with 1% KCl. Getting gas back, maintain 11.3 ECD and <150psi downstream of the choke. Out density increasing, ~11.3 ppg from RWO KWF. Clean KCl at surface at calc vol. 1:1 returns at 11.3 ECD, start increasing ECD up t 11.8 1.02bpm in and 0.67 bpm out at 1,108psi WHP at 11.5 ECD. Increase ECD to 11.8, 0.98 bpm in and 0.42 bpm out, losing ~27 BPH. Reduce ECD to 11.5, 1.97 in and 1.87 out, losing 6 bph Shut down pump and trap ~1,250psi WHP. Allow WHP to bleed off to stabilization to verify pore pressure. WHP = 1,152 at 11.78 ECD. WHP bled off to 1,027psi, online with pump at min rate, Pore pressure = ~11.2 ppg Decision made to cut our 11.8 KWF to 11.3ppg. Send vac truck to C-Pad UR to PU 10.8ppg brine and dilute some of our 11.8 down to 11.3ppg Swap to 11.3 brine. 11.3 back to surface, shut down pump and monitor. WHP at 41psi, bleed off pressure, bled back 1 bbl, close in bleeder and monitor pressure. Pressure increased to 46psi, open bleeder and pressure dropped to 34 psi and is slowly coming down Well was charged up a ~45 min to bleed back 0.5 bbls brine. Flow check for 10 min, well is dead. Online with pump well is full, POOH for WS pumping pipe displacement. Flow check at surface is good. PJSM then remove BHA #1. P/U BHA #2, whipstock BHA with Gyro. M/U injector to well. Service injector. Troubleshoot gyro tool. Continue troubleshoot gyro tool software. Break off injector and pick up tool to check scribe and surface test. Well is taking about 1.6 bph while troubleshooting. Finished troubleshooting and checking scribes. At surface Gyro tool giving consistent TF values but about 100 deg off of what is expected. Will RIH and check the consistency of the offset from the Gyro to the DGS values. M/U injector to well. RIH with BHA #2. Tie-in depth from 8,085'. Correct +1'. Log CCL across whipstock setting area. 5/2/2021 - Sunday Move pit mod from F-22 to F-05 Pit Mod set, accept rig at 07:30am. Start MIRU OPS. 10:20 notify State Rep Fluid pack all surface lines to shell test. Grease block valves on stack and choke. Change Pack offs Start testing BOPE as per AOGCC. Lou Laubenstein with AOGC on sight to witness testing. Test BOPs & Valves to 250/4,000 PSI. Test #1-7. Passing. Test #8 Top Rams on 3'' Showing leak through rams or above. Cycle rams, Still leaking, Pull test joint and check Closing area. Dress same. Retest still leaking. Pull test joint and check all connections. Found 4 O-Rings missing from 1 1/2 MT connections. Replace same. Retest rams. Good test. R/D Testing equipment & Prep for BHA #1. Blow down surface lines. Install Riser. Install Upper Quick and check valves and test to 4,000 psi. Good. Perform valve alignment check. Stab injector, Drop of quick test sub. Pump open surface safety valve and install fusible cap lock. Bleed down Hyds. PJSM, Open swabs and check well pressure. 970 PSI. P/U Nozzle BHA #1, Stab on injector, Displace out fresh water from coil with 8bbl of Methanol and 62 bbl of 1% Warm KCL. Open swab and RIH pumping .2 BPM. RIH with BHA #1 from surface T/ 6,000'. Circ taking returns to kill tank at .2 BPM. 5/3/2021 - Monday 4/30/2021 - Friday No operations to report 4/28/2021 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report 4/29/2021 - Thursday No operations to report Well Name Rig API Number Well Permit Number Start Date End Date MPU F-05L1 & L1-01 CDR2 50-029-22632-60 & 61-00 221-014 & 211-015 3/7/2021 5/4/2021 Hilcorp Alaska, LLC Weekly Operations Summary Finish CCL log. CCL shows the TT is 38' deeper than WBS and onl y 6' away from our TOWS set depth. Relog tie in and CCL to confirm, both logs are correct, discuss setting WS 5-10' deeper with town OE and DD's. Good to move WS down 5'. Discuss with OE, DD & MWD how we are going to set the WS PUH to 7,960' to set TF at new orientation of 85° ROHS. TF set, Up WT = 43k, RIH and set TOWS at 8,665'. On depth PU 2' to 35k, close EDC and set WS. WS set at 3000psi, set down 5k WOB to ensure its set Good set with 7.7k WOB and no movement, POOH for window milling BHA. Flow check at surface. Good no flow, LD BHA. MU the milling BHA and RIH. Log tie in with 0' correction. Open the EDC and RIH to tag. Tag at 8374, swap well to 8.8 mud maintaining 11.3ppg at the window Well swapped to 9.0ppg mud, start walking ECD up to 11.8 to check loss rate at 2.8 bpm. 1:1 returns, shut down the pump, close the EDC and start milling the window. Mill window F/ 8,374' T/ 8,377'. 2.8 BPM, 3808 psi Free Spin. MW 9.08. 11.75 ECD with 720 psi WHP. 2.86 in, 2.85 out. 13.0k Coil WT, WOB = Continue milling window F/ 8,377'. 2.88 / 2.88 bpm. MW 9.0 / 9.0 ppg In / Out. About 4 bbl/hr loss at 11.8# ECD. 8378' sample has trace D-shale. Window exit at 8379'. Drill 10' rathole. Pump 5 bbls hi-vis around. Conduct 1 reaming pass, dry drift is clean. Last sample is 15% shale, 10% cement. Circ well to 11.8#. Flow check is good, POOH. POOH with BHA #3. Flow check at surface is good. PJSM then lift off injector. L/d BHA #3. 5/4/2021 - Tuesday STATE OF ALASKA Reviewed By: `ke OIL AND GAS CONSERVATION COMMISSION P.1. Sup" S !p 4z{ BOPE Test Report for: MILNE PT UNIT F-05 - Comm Contractor/Rig No.: Nabors CDR2AC - PTDN: 1970740 - DATE: 5/2/2021 Inspector Lou Laubenstein - Insp Source Operator: Hilcorp Alaska, LLC - Operator Rep: Igtanloc / Sunderland Rig Rep: Erdman / Cozby Inspector Type Operation: WRKOV Sundry No: Type Test: INIT 1 321-075 Test Pressures: Rams: Annular: Valves: MASP: 250/4000 , 25012500 - 250/4000 - 3538 FLOOR SAFTY VALVES Quantity TEST DATA Upper Kelly MISC. INSPECTIONS: NA, MUD SYSTEM: 0 NA P/F 2 -_ Visual Alarm Inside BOP Location Gen.: _ P Trip Tank _PP , P- Housekeeping Housekeeping: P= Pit Level Indicators P " P - PTD On Location P- Flow Indicator P - P ' Standing Order Posted P _ Meth Gas Detector P ' P " Well Sign _P H2S Gas Detector P P_ Drl. Rig - P - MS Mise NA NA Hazard Sec. P Misc NA FLOOR SAFTY VALVES BOP STACK: Inspection No: bopLOL210506081802 Related Insp No: ACCUMULATOR SYSTEM: Time/Pressure P/F System Pressure 3000 P Pressure After Closure 2100 P 200 PSI Attained 17 P " Full Pressure Attained _ 55 - P Blind Switch Covers: Yes - P " Nitgn. Bottles (avg): 10 2160 - P_ - ACC Mise 0 NA CHOKE MANIFOLD: Quantity Size Quantity P/F Upper Kelly 0 NA, Lower Kelly 0 NA Ball Type 2 -_ P - Inside BOP 0 - NA FSV Misc 0 NA BOP STACK: Inspection No: bopLOL210506081802 Related Insp No: ACCUMULATOR SYSTEM: Time/Pressure P/F System Pressure 3000 P Pressure After Closure 2100 P 200 PSI Attained 17 P " Full Pressure Attained _ 55 - P Blind Switch Covers: Yes - P " Nitgn. Bottles (avg): 10 2160 - P_ - ACC Mise 0 NA CHOKE MANIFOLD: Quantity Size P/F Stripper 1 2 3/8" P " Annular Preventer I - 7 1/16" P #1 Rams _ 1 - Blind/Shear P_ #2 Rams 1 - 2 3/8" P 43 Rams 1 , 3" NT #4 Rams 1- 23/8" -_ P ' #5 Rams 0 __ NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/16" P " HCR Valves _ 2 - 2 1/16" ' P Kill Line Valves 1 - 2 1/16" ' P Check Valve 0 NA BOP Misc 2 - 2" piper - P Quantity P/F No. Valves 12 - P - Manual Chokes _ 1 P - Hydraulic Chokes I _ P__" CH Mise 0 NA INSIDE REEL VALVES: (Valid for Coil Rigs Only) Quantity P/F Inside Reel Valves 1 P Number of Failures: 0 ✓ Test Results Test Time 6.5 Remarks: Test was completed with a 2 3/8" and a 3" test joint, Wasn't able to aet a test for 3" rams (operator found 4 O rings missing; installed missing 0 rings and tested with 3" test jnt - passed after I left location). 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Run 4-1/2" completion 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 8,895'N/A Casing Collapse Conductor 470psi Surface 3,090psi Production 5,410psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name:Ian Toomey Operations Manager Contact Email:itoomey@hilcorp.com Contact Phone: 777-8520 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng N/A and N/A Tubing Size: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 2/25/2021 2-7/8" Perforation Depth MD (ft): See Schematic See Schematic N/A and N/A 112' 20" 9-5/8" 7" 5,570' 8,880' 5,750psi 7,240psi 4,576' 7,444' 5,570' 8,880' N/A MILNE PT UNIT KR F-05 112'112' 6.5# / L-80 / EUE 8rd TVD Burst 8,253' MD 1,490psi Length Size 7,459'8,797'7,361' C.O. 432D PRESENT WELL CONDITION SUMMARY 3,538 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0355023 197-074 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22762-00-00 Milne Point Field / Kuparuk River Oil Hilcorp Alaska LLC Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): COMMISSION USE ONLY Authorized Name: Authorized Title: ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Chad Helgeson (1517) 2021.02.09 07:46:52 - 09'00' By Samantha Carlisle at 8:49 am, Feb 09, 2021 321-075 DSR-2/9/21 0388235; ADL0025509 X DLB DLB 02/09/2021 10-407 MGR11FEB21 BOPE test to 4000 psi. Annular to 2500 psi. MPSP > 3000 ps requires 3 ram stack. 3,538 Comm 2/11/21 dts 2/11/2021 JLC 2/11/2021 RBDMS HEW 2/12/2021 CTD Setup Well: MPU F-05 Date: 2/05/21 Well Name:MPU F-05 API Number:50-029-222762-01-00 Current Status:SI Oil Well [failed ESP]Pad:F-Pad Estimated Start Date:February 25 th, 2021 Rig:Doyon 14 Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:197-074 First Call Engineer:Ian Toomey (907) 777-8434 (O) (907) 903-3987 (M) Second Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) AFE Number:TBD Job Type:CTD Setup Gauge Pressure:4,219 psi @ 6,815’ TVD |EMW = 11.91 ppg Maximum Expected BHP:4,219 psi @ 6,815’ TVD |KWF = 12.2 ppg MPSP:3,538 psi Gas Column Gradient = 0.1 psi/ft Max Inclination:61° @ 5,224’ MD Max Dogleg:3.7°/100ft @ 5,988’ MD Tree:Cameron 2-9/16” 5M Wellhead:FMC, 11” x 7-1/16” 5M, Gen 5A Tubing Hanger Lift threads:2-7/8” EUE 8rd top & bottom BPV Profile:2-1/2” CIW Type H Brief Well Summary: Well F-05 was drilled by Nabors 22E, perforated/fractured and completed by Nabors 4ES in May 1997 as a Kuparuk A2-sand producer. RWO’s to replace the ESP in 7/97, 4/00, 12/00 & 2/01 due to frac sand. During the ESP replacement in June 2001, 250 micron screens were installed to prevent frac sand production. This ESP ran until early May 2005 when it shut down due to an electrical failure. During the RWO in late May 2005 the screens were pulled and the A1 & A3 sands were perforated. The ESP was replaced in June 2012. This ESP failed in November 2015 and was SI. Due to high BHP and with approval from the AOGCC the well has been free flowing since December 2020 to lower the BHP. Notes Regarding the Well & Design x 7” Casing MIT to 2,500 psi passed on 6/20/2012 down to 8,400’ with 11.9 ppg brine. x Well free flowing at 372 psi on the tubing, making 45 BOPD, 150 BWPD and 50 MCF of gas (last test on 1/28/21) x Offset Injector Support o L-33: SI on 12/22/2020 Objective: x Pull 2-7/8” ESP completion. x Run new 4-1/2” completion to setup the well for CTD. Pre-Rig Procedure: 1. RD well house and flowlines. Clear and level area around the well. 2. Set 2-1/2” BPV. CTD Setup Well: MPU F-05 Date: 2/05/21 RWO Procedure: 3. MIRU Doyon 14, ancillary equipment and lines to returns tank. 4. Pull the BPV. Bleed gas to 0 psi on the tubing and IA (if needed). 5. Circulate a minimum 300 bbls of 12.2 ppg LSND down the tubing taking returns up the IA to the kill tank until clean 12.2 ppg mud is seen at surface. 6. Monitor to confirm the well is dead for 30 minutes. If not, contact Operations Engineer and record SITP/SICP. 7. Set 2-1/2” HP BPV. 8. ND Tree. Inspect the lift threads on the tubing hanger. Install the plug off tool into the BPV. 9. NU 13-5/8” BOP stack with 2-7/8” x 5” VBR’s in the upper and lower ram cavities. 10. Test BOPE to 250/4,000 psi and annular to 250/2,500 psi. a. Notify the AOGCC 24 hours in advance of BOP test. b. Confirm test pressures per the Sundry Conditions of approval. c. Test VBR’s and annular with 2-7/8” & 4-1/2” test joints. d. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. Contingency: If BOPE test fails a. Notify Operations Engineer (Hilcorp), Mr. Mel Rixse (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test if test witness was waived. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 11. RU to pull 2-7/8” ESP completion. 12. Pull plug off tool, check for pressure under the BPV, if needed kill the well with KWF and pull the BPV. 13. MU the landing joint to the tubing hanger, BOLDS and unseat the tubing hanger. a. String PU = 95K and SO = 80K when landed by Doyon 16 (block weight = 40K) in 11.9 ppg brine. 14. Pull the hanger to the rig floor. Lay down the landing joint and tubing hanger. RU to pull ESP over sheaves to spooling units. a. Inspect the tubing hanger and note any corrosion or damage. Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger or test plug in tubing head. Test BOPE per standard procedure and sundry. 15. POOH laying down the 2-7/8” tubing spooling ESP cable and removing all jewelry as it presents itself until there is the desired weight for the storm packer (~25K). 16. Cut the ESP cable and secure to the tubing. PU and MU the 7” storm packer. CTD Setup Well: MPU F-05 Date: 2/05/21 17. RIH and set at the storm packer at ±55’. Release from the storm packer, POOH and lay down the running tool. 18. PT to 1,500 psi for 10 minutes. 19. ND the BOP stack and set back. ND the tubing head. NU the new tubing head. PT 7” pack-off and void to 250/5,000 psi. 20. NU the BOP stack, set the test plug, PT the break to 250/4,000 psi and pull the test plug. 21. PU, MU and RIH with the storm packer retrieval tool. Engage the storm packer, release, POOH and lay down. 22. Continue to POOH laying down the 2-7/8” tubing spooling ESP cable and removing all jewelry as it presents itself. Lay down ESP components. a. Note any corrosion, sand, scale, damage or over torqued connections on the tubing with associated depths and ESP components on the morning report. Equipment Disposition Tubing hanger Visually inspect on site then restock or junk Tubing & Pup joints Junk Gaslift Mandrels/Nipple Junk ESP equipment/Power Cable Centrilift to take possession for inspection and teardown Protectorlizer (6)Junk Single Clamps (2)Junk Armster Guards (3)Junk Cannon clamps (138)Junk 23. RD ESP pulling equipment. 24. RU to run 4-1/2” completion. 25. PU and MU the following completion. a. WLEG/Mule shoe b. 1 joint, 4-1/2”, 12.6#, L-80, TXPM c. Nipple, 3.813” X profile, 4-1/2”, TXPM (RHC plug body installed), with 10’ handling pups d. 1 joint, 4-1/2”, 12.6#, L-80, TXPM e. Pup joint, 1 joint, 4-1/2”, 12.6#, L-80, TXPM f. Crossover, 4-1/2” EUE 8rd Box x 4-1/2” TXP Pin g. Retrievable Packer, Halliburton AHR, 4-1/2”, 12.6#, L-80 EUE 8rd (setting depth ~8,192’) h. Crossover, 4-1/2” TXPM Box x 4-1/2” EUE 8rd Pin i. Pup joint, 4-1/2”, 12.6#, L-80, TXPM j. 1 joint, 4-1/2”, 12.6#, L-80, TXPM k. Pup joint, 4-1/2”, 12.6#, L-80, TXPM l. Crossover, 4-1/2” EUE 8rd Box x 4-1/2” TXP Pin m. Ported Pressure Sub, 4-1/2”, 12.6#, L-80, EUE 8rd n. Crossover, 4-1/2” TXPM Box x 4-1/2” EUE 8rd Pin o. Pup joint, 4-1/2”, 12.6#, L-80, TXPM CTD Setup Well: MPU F-05 Date: 2/05/21 p. Crossover, 4-1/2” H521 Box x 4-1/2” TXP Pin q. Sliding Sleeve, 4-1/2”, 12.6#, L-80 Hydril 521 r. Crossover, 4-1/2” TXPM Box x 4-1/2” H521 Pin s. Pup joint, 4-1/2”, 12.6#, L-80, TXPM t. Crossover, 4-1/2” EUE 8rd Box x 4-1/2” TXP Pin u. Gauge Carrier, 4-1/2”, 12.6#, L-80, EUE 8rd v. Crossover, 4-1/2” TXPM Box x 4-1/2” EUE 8rd Pin w. Pup joint, 4-1/2”, 12.6#, L-80, TXPM x. XXX joints, 4-1/2”, 12.6#, L-80, TXPM 26. PU and MU the 4-1/2” tubing hanger. Make final splice of the TEC wire and ensure any unused control line ports are dummied off. 27. Land tubing hanger and RILDS. Lay down landing joint. Record PU and SO weights on the tally and WellEZ. 28. Set 4” HP BPV. 29. ND BOPE. Install the plug off tool. 30. NU the tubing head adapter and NU 4-1/16” 5M tree. 31. PT the tubing hanger void to 500/5,000 psi. PT the tree to 250/5,000 psi. 32. Pull the plug off tool and BPV. 33. Reverse circulate the well over to corrosion inhibited seawater follow by diesel freeze protect to 2,500’ MD. 34. Drop the ball & rod. 35. Pressure up on the tubing to 3,500 psi to set the packer. PT the tubing to 3,500 psi for 30 minutes (charted). 36. Bleed the tubing pressure to 2,000 psi and PT the IA to 3,500 psi for 30 minutes (charted). Bleed both the IA and tubing to 0 psi. 37. Turn well over to production via handover form. Post-Rig Procedure: 38. RU slickline. 39. Pull the ball & rod and RHC plug body. 40. RD slickline. CTD Rig Work (scheduled to begin in May 2021 under separate 10-401 sundry): 1. MIRU and test BOPE. 2. Set 4-1/2” x 7” whipstock at 8,405’ (top) 3. Mill 3.80” single string window out of the 7” casing plus 10’ of rathole. 4. Driling 4-1/4” CTD sidetrack to TD of 11,299’. a. Kickoff in the Kuparuk B-sand b. Drill down to the Kuparuk A-sand (primary target) 5. Run 2-7/8” L-80 slotted/solid liner with billet to TD (top of liner at ±9,578’). 6. Kickoff billet and drill 4-1/4” CTD sidetrack to TD of 11,225’. 7. Run 2-7/8” L-80 slotted/solid liner to TD 8. Freeze protect the well with diesel. PTD Sundry 321-075 CTD Setup Well: MPU F-05 Date: 2/05/21 9. RDMO. See 10-401 PTD for CTD procedure for more detail Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP stack sketch 4. Blank RWO MOC Form _____________________________________________________________________________________ Revised By: IAT 2/02/2021 SCHEMATIC Milne Point Unit Well: MP F-05 Last Completed: 6/22/2012 PTD: 197-074 TD =8,895’ (MD) / TD =7,459’(TVD) 20” Orig. KB Elev.: 29’/ GL Elev.: 12.3’ 7” 3 5 6 7 8 9 10 9-5/8” ES Cementer @ 2,005 MD 9-5/8” 1 2 KUP A3 Sands PBTD =8,797’(MD) / PBTD = 7,361’(TVD) 4 9 KUP A2 Sands KUP A1 Sands Two 7” x 21’ Marker Joints f/ 8,273’ – 8,314’ RKB CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surf 112' 9-5/8" Surface 40 / L-80 / Btrc. 8.679 Surf 5,570’ 7" Production 26 / L-80 / Btc Mod 6.151 Surface 8,880’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.347 Surf 8,253’ JEWELRY DETAIL No Depth Item 1 138’ Camco 2-7/8” x 1” KBMG-M-2 GLM w/ DPSOV 2 7,996’ Camco 2-7/8” x 1” KBMG-M-2 GLM w/Empty Pocket 3 8,149’ HES XN - Nipple 2-7/8”(2.25 No-go ID) 4 8,190’ WellLift Discharge Gauge Unit 5 8,195’ Centrilift Pump 137-P17, Model SXD 6 8,214’ Centrilift Gas Separator GRSFTX 7 8,219’ Tandem Seal Section GSB3DB UT/LT SB/SB PFSA CL6 8 8,233’ Motor, 190HP, 2415 Volt, 48 amp, Model KMH 9 8,249’ PumpMate XTO w/ 6 Fin Centralizer 6,813’ TVD/ Bott. 8,253’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A3 Sands 8,460’ 8,472’ 7,024’ 7,036’ 12 5/31/2005 Open Kup. A2 Sands 8,478’ 8,498’ 7,042’ 7,062’ 20 5/18/1997 Open Kup. A1 Sands 8,503’ 8,523’ 7,067’ 7,087’ 20 5/31/2005 Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I (Approx.) in 24” Hole 9-5/8" Cmt w/ 1,436 sks PF “E”, 600 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 250 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 2,000’ Max Hole Angle = 61 deg. @ 5,220’ Hole Angle through perforations = > 1 deg. TREE & WELLHEAD Tree 2-9/16” 5M Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr., 3” LH ACME on top and 2-7/8” EU 8rd on bottom, 2.5” CIW BPV Profile GENERAL WELL INFO API: 50-029-22762-00-00 Drilled and Cased by Nabors 22E - 5/7/1997 1st Perforated w/ Wireline – 5/18/1997 ESP Completion #1 w/ Nabors 4-ES – 5/24/1997 ESP RWO w/ Nabors 4-ES – 7/99, 4/00, 12/00 & 2/01 ESP RWO, Add Screens w/ Nabors 4-ES – 6/15/2001 ESP RWO, Remove Screens & Add Perfs w/ Nabors 4-ES – 5/30/2005 ESP RWO w/ Doyon 16 – 6/28/2012 NOTES: _____________________________________________________________________________________ Revised By: IAT 2/02/2021 PROPOSED Milne Point Unit Well: MP F-05 Last Completed: 6/22/2012 PTD: 197-074 TD =8,895’ (MD) / TD = 7,459’(TVD) 20” Orig. KB Elev.: 29’/ GL Elev.: 12.3’ 7” 3 5 6 7 9 9-5/8” ES Cementer @ 2,005 MD 9-5/8 ” 1 2 KUP A3 Sands PBTD =8,797’(MD) / PBTD = 7,361’(TVD) 4 KUP A2 Sands KUP A1 Sands Two 7” x 21’ Marker Joints f/ 8,273’ – 8,314’ RKB CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surf 112' 9-5/8" Surface 40 / L-80 / Btrc. 8.679 Surf 5,570’ 7" Production 26 / L-80 / Btc Mod 6.276 Surface 8,880’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surf ±8,253’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A3 Sands 8,460’ 8,472’ 7,024’ 7,036’ 12 5/31/2005 Open Kup. A2 Sands 8,478’ 8,498’ 7,042’ 7,062’ 20 5/18/1997 Open Kup. A1 Sands 8,503’ 8,523’ 7,067’ 7,087’ 20 5/31/2005 Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I (Approx.) in 24” Hole 9-5/8" Cmt w/ 1,436 sks PF “E”, 600 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 250 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 2,000’ Max Hole Angle = 61 deg. @ 5,220’ Hole Angle through perforations = > 1 deg. TREE & WELLHEAD Tree 2-9/16” 5M Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr., 3” LH ACME on top and 2-7/8” EU 8rd on bottom, 2.5” CIW BPV Profile GENERAL WELL INFO API: 50-029-22762-00-00 Drilled and Cased by Nabors 22E - 5/7/1997 1st Perforated w/ Wireline – 5/18/1997 ESP Completion #1 w/ Nabors 4-ES – 5/24/1997 ESP RWO w/ Nabors 4-ES – 7/99, 4/00, 12/00 & 2/01 ESP RWO, Add Screens w/ Nabors 4-ES – 6/15/2001 ESP RWO, Remove Screens & Add Perfs w/ Nabors 4-ES – 5/30/2005 ESP RWO w/ Doyon 16 – 6/28/2012 NOTES: JEWELRY DETAIL No Depth Item 1 ±24’ 4-1/2” Tubing Hanger 2 ±8,114’ Gauge Carrier 3 ±8,124’ Sliding Sleeve 4 ±8,134’ Ported Pressure Sub 5 ±8,192’ Retrievable Packer 6 ±8,254’ Nipple, 3.813” X 7 ±8,305’ WELG, bottom at ±8,306’ ] Milne Point Doyon 14 13-5/8” BOP Stack Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: February 5th, 2021Subject: Changes to Approved Sundry Procedure for Well MP F-05Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Step Page Date Procedure ChangeHAKPreparedBy (Initials)HAKApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Operations Manager DatePrepared:Operations Engineer Date • • Schwartz, Guy L (DOA) ' 74 t' From: Schwartz, Guy L(DOA) Sent: Tuesday, March 15, 2016 1:46 PM To: 'Tom Fouts'; samantha.carlisle@alaska.gov Cc: Stan Porhola;Ted Kramer; Paul Chan Subject: RE: Sundry 315-111 Expiration - MP F-05/API 50-029-22762-00/ PTD 197-074 Tom, AOGCC Will retract 315-111 as requested. (ESP swap on F-05) Guy Schwartz Sr. Petroleum Engineer 1�Pn 0 42016 AOGCC e%WEC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Tom Fouts [mailto:tfouts@hilcorp.com] Sent: Tuesday, March 15, 2016 1:37 PM To: Schwartz, Guy L (DOA) Cc: Stan Porhola; Ted Kramer; Paul Chan Subject: Sundry 315-111 Expiration - MP F-05 / API 50-029-22762-00/ PTD 197-074 Guy, We are removing Sundry 311-111 from our work cue since it has been over a year since it was approved. Thanks, Tom Fouts Senior Ops/Reg Tech Hilcorp Alaska, LLC tfouts@hilcorp.com Direct: (907)777-8398 Mobile: (907) 351-5749 1 RBDMS 1,47 MAI 2 2016 �`'�\�of y/,�T�� w\� s,?, THE STATE Alaska Oil and Gas �� , of �� LAsKA Conservation Commission _ A Witt333 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 wR Main: 907.279.1433 ALAS Fax: 907 276.7542 www.aogcc alaska.gov „ft ti Chris Kanyer 4.11 J L Operations Engineer q "� Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR F-05 Sundry Number: 315-111 Dear Mr. Kanyer: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. F•erster Chair, Commissioner DATED this 2 day of March, 2015 Encl. . RECEIVED STATE OF ALASKA• FEB 2 6 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ®�� 20 MC 25.280 n�L 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool 0 Repair Well[f M Change Approved Program ❑ Suspend❑ , Plug Perforations❑ Perforate❑ Pull Tubing Q. Time Extension 0 Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate 0 After Casing❑ Other. ESP Changeout 2 2.Operator Name: 4.Current Well Class: 5.Permit to Dril Number. Hilcorp Alaska,LLC Exploratory ❑ Development 0• 197-074 3.Address: Stratigraphic 0 Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22762-00-00 . 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? C.O.432C✓ Will planned perforations require a spacing exception? Yes El No 0 I MILNE PT UNIT KR F-05 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0355023 Milne Point Field/Kuparuk River Oil• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 8,895 - 7,459'• 8,797' - 7,361' - N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' 1,490psi 470psi Surface 5,570' 9-5/8" 5,570' 4,576' 5,750psi 3,090psi Intermediate Production 8,880' 7" 8,880' 7,444' 7,240psi 5,410psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic I See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8rd 8,253' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): N/A and N/A N/A and N/A • 12.Attachments: Description Summary of Proposal 0 ' 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch E Exploratory ❑ Stratigraphic❑ Development 2. Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 3/11/2015 Commencing Operations: Oil Q • Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned 0 Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer Email ckanyer@hilcorp.com Printed Name Chris Kanyer Title Operations Engineer i // s Signature ' /G t, �Lr� Phone 777-8377 Date 2/26/2015 777 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31S— k11 Plug Integrity ❑ BOP Test [r Mechanical Integrity Test ❑ Location Clearance ❑ \\ Other: -k- 3 000 ,S ae'F' _/c5- /ij 4S fo _ / SOS c 5` ) Spacing Exception Required? Yes ❑ No E Subsequent Form Required: f 0 —y 0 4' APPROVED BY Approved by:j ( ,,,,..„ste. ......„ COMMISSIONER 211- 115- �' THE COMMISSION Date: 3-Z / 1 3.2-16 OrRdIa0cftfcis, kIr 94 'l 'I 'Al,- Submit Form and o 03i10/2012 12 months from the data of appro`a. Attachments in Duplicate RBDMAR - L mei 2-,z.-i.5 Well Prognosis Well: MPF-05 Elilcorp Alaska,LL Date:2/26/2015 Well Name: MPF-05 API Number: 50-029-22762-00-00 Current Status: SI Producer Pad: F Pad Estimated Start Date: March 11, 2015 Rig: Nordic 3 Reg.Approval Req'd? March 10, 2015 Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 197-074 First Call Engineer: Chris Kanyer (907) 777-8377 (0) (907) 250-0374 (M) Second Call Engineer: Bo York (907) 777-8345 (0) (907) 727-9247 (M) AFE Number: 1520160 Current Bottom Hole Pressure: —4,402 psi @ 7,000' TVD (Last BHP measured 2/8/2015) Maximum Expected BHP: —4,402 psi @ 7,000' TVD (No new perfs being added) Max. Allowable Surface Pressure: 1,505 psi (Based on actual reservoir conditions and water cut of 89% (0.428psi/ft) with an added safety factor of 1000' TVD of oil cap) Brief Well Summary: The Milne Point F-05 well was drilled as a Kuparuk development well that TD'd at a depth of 8,895' and ran and cemented 7" production casing in May 1997. The well was perforated and Frac'd in the Kuparuk A sands and initially completed with an ESP. The well has had ESPs failed and replaced in June 1997, July 1997, April 2000, December 2000, February 2001, June 2001, and 2005. In June 2005 the Kuparuk Al & A3 sands were perforated and an ESP was run. A subsequent failed ESP was changed out in 2012.The recent pump was shut in due to a probable ESP shaft break in December 2014. The well has remained shut in ever since. A recent casing pressure test was performed on 6/20/2012 to 2,500psi. .- There is currently no significant scale issues observed on this well. No subsidence issues are expected in this well. Notes Regarding Wellbore Condition 7 Current well status is shut in oil producer. No subsidence issue suspected. RWO Objective: Pull ESP, perform fill cleanout, & run 2-7/8" ESP completion with downhole chemical injection. Brief Procedure: 1. MIRU Nordic#3 Rig. 2. Circulate well with 8.5ppg seawater and monitor well. 3. If necessary, circulate well with 12.1ppg brine (or appropriate kill weight fluid. [Note: Well currently has a functioning downhole gauge]. Monitor well. 4. ND tree, NU 13-3/8" BOPE with 11" spool adapter and test to 250psi low/3,000psi high, annular to 250psi low/2,500psi high. a. Notify AOGCC 24hrs in advance to witness test. 5. Unseat hanger and pull 2-7/8" ESP completion from 8,253' to surface and lay down same. 6. RIH with 7" cleanout BHA to +/-8,750'. POOH with same. 11 Well Prognosis Well: MPF-05 " tla.k .IA' Date: 2/26/2015 7. MU and RIH with ESP with gas separator on 2-7/8" 8RD EUE L-80 tubing [to be replaced if necessary]. Set ESP at+/-8,253'. Land tubing hanger. 8. ND BOP, NU and tree. 9. RDMO workover rig and equipment. 10. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic Milne Point Unit Well: MPF-05 • SCHEMATIC Last Completed: 6/22/2012 Hilcorp Alaska.LLC PTD: 197-074 CASING DETAIL Orig.KB Elev.:29'/GL Elev.:12.3' Size Type Wt/Grade/Conn Drift ID Top Btm 20" Conductor 91.1/H-40/N/A N/A Surf 112' .i 20' 9-5/8" . Surface 40/L-80/Btrc. 8.679 Surf 5,570' 7" Production 26/L-80/Btc Mod 6.151 Surface 8,880' 9-5/8"ES it I 1 • TUBING DETAIL Cementer @ 2,005 ND [ 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.347 Surf 8,253' 7 JEWELRY DETAIL No Depth Item 1 138' Camco 2-7/8"x 1"KBMG-M-2 GLM w/DPSOV 2 7,996' Camco 2-7/8"x 1"KBMG-M-2 GLM w/DGLV g5/g' , i 3 8,149' HES XN-Nipple 2-7/8" (2.2005 No-go ID) 4 8,190' WeIILift Discharge Gauge Unit 5 8,195' Centrilift Pump 137-P17,Model SXD 6 8,214' Centrilift Gas Separator GRSFTX 7 8,219' Tandem Seal Section GSB3DB UT/LT SB/SB PFSA CL6 8 8,233' Motor,19OHP,2415 Volt,48 amp,Model KMH 9 8,249' PumpMate XTO w/6 Fin Centralizer 6,813'TVD/Bott.8,253' PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Kup.A3 Sands 8,460' 8,472' 7,024' 7,036' 12 5/31/2005 Open __ Kup.A2 Sands 8,478' 8,498' 7,042' 7,062' 20 5/18/1997 Open Kup.Al Sands 8,503' 8,523' 7,067' 7,087' 20 5/31/2005 Open WELL INCLINATION DETAIL KOP @ 2,000' Max Hole Angle=61 deg. @ 5,220' Hole Angle through perforations=>1 deg. OPEN HOLE/CEMENT DETAIL 20" Cmt w/250 sks of Arcticset I(Approx.)in 24"Hole 9-5/8" Cmt w/1,436 sks PF"E",600 sx Class"G"in 12-1/4"Hole 2 7" Cmt w/250 sks Class"G"in 8-1/2"Hole u TREE &WELLHEAD Tree 2-9/16"5M Wellhead 11"x 7-1/16"SM FMC Gen 5A,w/2-7/8"FMC Tbg.Hngr.,3"LH Two T x 21'Marker' ' 3 ACME on top and 2-7/8"EU 8rd on bottom,2.5"CIW BPV Profile Jdnts fl 8,273'- . I 8,314'RKB 1 GENERAL WELL INFO . L.-A API:50-029-22762-00-00 Drilled and Cased by Nabors 22E -5/7/1997 4 1`t Perforated w/Wireline-5/18/1997 IESP Completion#1 w/Nabors 4-ES-5/24/1997 • I_tlil `5 6 ESP RWO w/Nabors 4-ES-12/99& 2/00 '7 ESP RWO,Remove Screens&Add Perfs w/Nabors 4-ES-5/30/2005 ESP RWO w/Doyon 16-6/28/2012 NOTE: 8 Need Cementing Report to Establish Tops n9 1 D ..KUP A3 Sands =}KUP A2 Sands }KIP Al Sands TD=8,895'(MD)/TD=7,459'(TVD) PBTD=8,797'(MD)/PBTD=7,361'(R/D) Created By:CVK 2/26/2015 Milne Point Unit Well: MPF-05 • PROPOSED Last Completed: 6/22/2012 Hilcorp Ala.ka,tic c PTD: 197-074 CASING DETAIL Orig.KB Elev.:29'/GL Elev.:12.3' Size Type Wt/Grade/Conn Drift ID Top Btm 20" Conductor 91.1/H-40/N/A N/A Surface 112' 20' 9-5/8" Surface 40/L-80/Btrc. 8.679 Surface 5,570' 7" Production 26/L-80/Btc Mod 6.151 Surface 8,880' 9-5/8'ES • TUBING DETAIL Cementer @ 2,005 MJ Tubing 6.5/L-80/EUE 8rd 2.347 Surface ±8,253' JEWELRY DETAIL No Depth Item 95/8 • 1 ±138' GLM 2 ±7,996' GLM 3 ±8,149' HES XN-Nipple 4 ±8,190' Discharge Gauge Unit 5 ±8,195' Pump 6 ±8,214' Gas Separator 7 ±8,219' Tandem Seal Section 8 ±8,233' Motor 9 ±8,249' PumpMate XTn.,,%6 Fin Centralizer Bott.±8,253' PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(ND) FT Date Status Kup.A3 Sands 8,460' 8,472' 7,024' 7,036' 12 5/31/2005 Open Kup.A2 Sands 8,478' 8,498' 7,042' 7,062' 20 5/18/1997 Open Kup.Al Sands 8,503' 8,523' 7,067' 7,087' 20 5/31/2005 Open WELL INCLINATION DETAIL KOP @ 2,000' Max Hole Angle=61 deg. @ 5,220' Hole Angle through perforations=>1 deg. OPEN HOLE/CEMENT DETAIL 20" Cmt w/250 sks of Arcticset I(Approx.)in 24"Hole si 2 9-5/8" Cmt w/1,436 sks PF"E",600 sx Class"G"in 12-1/4"Hole 7" Cmt w/250 sks Class"G"in 8-1/2"Hole TREE &WELLHEAD Tree 2-9/16"5M Tv.oT'x21'Maker' Wellhead 11"x 7-1/16"5M FMC Gen 5A,w/2-7/8"FMC Tbg.Hngr.,3"LH Jdntsf/8,273'- ACME on top and 2-7/8"EU 8rd on bottom,2.5"CIW BPV Profile 8,314'RKB 111 a GENERAL WELL INFO API:50-029-22762-00-00 4 Drilled and Cased by Nabors 22E -5/7/1997 1st Perforated w/Wireline-5/18/1997 GP,GP 5 6 ESP Completion#1 w/Nabors 4-ES-5/24/1997 ti 7 ESP RWO w/Nabors 4-ES-12/99& 2/00 ESP RWO,Remove Screens&Add Perfs w/Nabors 4-ES-5/30/2005 ESP RWO w/Doyon 16-6/28/2012 8 Need Cementing Report to Establish Tops 9 10 =.KUP A3 Sands .KUP A2 Sands KLP Al Sands 7"/ I. TD=8,895'(MD)/TD=7,459'111/D) PBTD=8,797'(MD)/PBTD=7,361'(TVD) Created By:CVK 2/26/2015 MPU BOP Stack r 1 O uaraoiLiti i Hydril 13 5/8 5M , rail ill iiil r 13 5/8 5M '� �� 2 7/8"-5-%" variables 140.111P Mg Mg IIIP Spacer spool 13 5/8 5M _ 13 5/8 5M —t' rl 1 s Blinds [1111111011:11 � � �%{ . ,� ; � �'!'/j�'�{)'/��a ;- ,q� c 3 7 J ,'� ! .� 4,� i tT�� 41_ i_i - COP NIP Mg Ing Ille Spacer spool 13 5/8 SM ,iiiii 13 5/8" 5MX11" 5M DSA 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday, February 27, 2015 2:34 PM To: 'Chris Kanyer' Cc: Tom Fouts Subject: RE: MPF-05: (PTD 197-074) Pre-RWO Waterflood Management Chris, As we discussed you have approval to continue to produce MPF-05 to reduce BHP.This is in order to facilitate the upcoming RWO to replace ESP. PS.. don't forget to put in PTD#in the email subject line. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:[his e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guv.schwartz@alaska.gov). From: Chris Kanyer [mailto:ckanyer@ihilcorp.com] Sent: Friday, February 27, 2015 12:46 PM To: Schwartz, Guy L (DOA) Cc: Tom Fouts Subject: MPF-05: Pre-RWO Waterflood Management Guy, As discussed, prior to the upcoming rig workover(RWO) on well MPF-05 (API#50-029-22762-00-00 PTD197-074), we are currently managing the well's bottom hole pressure (BHP) by shutting in offset injectors. Here is the associated information you requested: MPF-05 od-' • Gross fluid rate prior to ESP failure =850bfpd • ESP failed 12/27/14. • Latest static taken 2/08/15—4401psi at datum, 12.1ppg EMW, Has a working BH gauge `�\� MPL-33 WINJ: • Shut in and freeze protected on 1/22/15. No other current offset injection. We plan to produce the MPF-05 by opening it to flow through the tubing until the well's BHP is low enough for us to safely perform the RWO as planned on sundry submitted on 2/26/2015. Please advise regarding any additional steps to move forward. 1 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN Color items- Pages: [] Grayscale, halftones, pictures, graphs, charts - Pages: [] Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA n Diskettes, No. [] Other, No/Type 'OVERSIZED [] .Logs of various kinds [] Other Complete COMMENTS: Scanned by: E~v~y Miidred-D'aretha ~ Lowell Date..' TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: /si - STATE OF ALASKA AL KA OIL AND GAS CONSERVATION COOSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Stimulate - Frac ❑ Waiver ® Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Stimulate - Other ❑ Time Extension Change out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ® Development ❑ Exploratory ' 197 - 074 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 029 - 22762 - 00 - 00 7. Property Designation (Lease Number): Zm 1 t 8. Well Name and Number: ADL 025509 & 388235 355 0 A3 MPF - - 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field / Pool(s): ,- Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 8895 feet Plugs (measured) N/A feet ,,,„ f/ true vertical 7459 feet Junk (measured) N/A feet t t EC) Effective depth: measured 8797 feet Packer: (measured) None feet JUL true vertical 7361 feet Packer: (true vertical) feet z � 1 2 Casing Length Size MD TVD Burs " Structural V � / Conductor 78' 20" 112' 112' 1490 470 Surface 5538' 9 -5/8" 5570' 4576' 5750 3090 Intermediate Production 8853' 7" 8880' 7444' 7240 5410 Liner JtiL 1 20 Perforation Depth: Measured Depth: 8460' - 8523' True Vertical Depth: 7024' - 7087' Tubing (size, grade, measured and true vertical depth): 2 - 7/8 ", 6.5# L - 8253' 6817' Packers and SSSV (type, measured and true vertical depth): None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 94 35 952 310 273 Subsequent to operation: 73 47 1570 260 219 14. Attachments: ❑Copies of Logs and Surveys run 15. Well Class after work: ❑ Exploratory 0 Development ❑ Service ❑ Stratigraphic 0 Daily Report of Well Operations 16. Well Status after work: - ® Oil ❑ Gas ❑ WDSPL ■3 Well Schematic Diagram ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Sean McLaughlin, 564 -4387 N/A Printed a J.: Z r a Title Drilling Technologist Ike / / (' f � ii + Jo e Last fka, 564 -4091 Signatur Phone 5 64 4091 D ate Form 10 -404 Revised 11/20 I. JUL 11 2,012 ;,Jet Submit Original Only 7 / _ 12. ,,..,..7.7/._._ • S a Y d ; Common Well Name: MPF -05 AFE No Event Type: WORKOVER (WO) Start Date: 6/16/2012 End Date: X4- 00WC0 -E (1,700,000.00 USD) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/29/1997 12:00:00AM Rig Release: 6/22/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @31.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 6/16/2012 00:00 - 06:00 6.00 MOB P PRE PJSM, REVIEW RIG MOVE PROCEDURE - DISCUSS MAINTAINING GOOD RADIO AND VERBAL COMMUNICATION AT ALL TIMES - ASSIGN POSITIONS AND RESPONSIBILITIES AND WHAT TO WATCH FOR - WSL AND PAD OPERATOR PRESENT WHEN PULLING OFF WELL MOVE OFF OF MPF -18 - SPOT RIG OVER MPF -05 SHIM RIG, CLOSE CELLAR DOORS, SPOT CUTTINGS TANK - RIG ACCEPTED @ 06:00 HRS, 12/16/2012. 06:00 - 08:00 2.00 KILLW P DECOMP TAKE ON 11.9 PPG BRINE. - (2) UPRIGHT TANKS ON L PAD HAVE 275 BBLS EACH 11.9 PPG. BRINE. - CHECK 0/A PRESSURE = 0 PSI, VA = 1425 PSI. - FUNCTION TEST SSV ACTUATOR, OK. 08:00 - 08:30 0.50 KILLW P DECOMP EVACUATION DRILL WITH "D" CREW, (SIMULATED GAS RELEASE IN CELLAR) ALL HANDS REPORTED TO MUSTER AREA, (WSL SHACK). - FORKLIFT OPERATOR SECURED THE PAD AT THE ENTRANCE. DRILLER AND FLOOR HAND DONNED AIR PACKS AND SWEPT THE RIG. - NO MAN LEFT BEHIND. WELL SECURE. AAR. 08:30 - 12:00 3.50 KILLW P DECOMP SPOT FLOW BACK TANK AND RIG UP HARDLINE. - HARD LINERS PT'D HARD LINE TO 250 / 4000 PSI, OK. - PREP FOR WELL KILL. 12:00 - 12:30 0.50 KILLW P DECOMP SERVICE RIG, INSPECT EQUIPMENT. 12:30 - 14:00 1.50 KILLW P DECOMP PJSM. RIG UP TO PRESSURE TEST LINES. - PRESSURE TEST ALL LINES TO BE USED IN WELL KILL. - ALL 1502 UNIONS TESTED, 250 / 3500 PSI, 5 MINUTES / CHARTED. - TEST (2) CHECK VALVES ON KILL MANIFOLD, BOTH HOLDING SOLID. - RIG DOWN TEST EQUIPMENT. 14:00 - 15:30 1.50 KILLW P DECOMP EVACUATION DRILL WITH "A" CREW, (SIMULATED GAS RELEASE IN CELLAR) - ALL HANDS REPORTED TO MUSTER AREA, (WSL SHACK). - FORKLIFT OPERATOR SECURED THE PAD AT THE ENTRANCE. - DRILLER AND FLOOR HAND DONNED AIR PACKS AND SWEPT THE RIG. - NO MAN LEFT BEHIND. WELL SECURE. AAR. 15:30 - 17:30 2.00 KILLW P DECOMP PJSM, PICK UP DSM LUBRICATOR - PRESSURE TEST LUBRICATOR 250 / 5000 PSI, 5 MIN / CHARTED. - PUMP OPEN SSV W/ RIG REMOTE STATION. - UNSEAT BPV VALVE, NOTE 1425 PSI SITP. - PULL BPV, CLOSE MASTER AND SSV AND BREAK OUT / LD LUBRICATOR AND BPV Printed 7/9/2012 10:22:39AM ./" ,4i , ' / //efir _a e .. M, Common Well Name: MPF -05 AFE No Event Type: WORKOVER (WO) Start Date: 6/16/2012 End Date: X4- 00WC0 -E (1,700,000.00 USD) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/29/1997 12:00:00AM Rig Release: 6/22/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @31.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:30 - 00:00 6.50 KILLW P DECOMP WAIT ON DAY CREW TO KILL WELL - PERFORM RIG MAINTAINENCE - CLEAN AND PAINT PROJECTS - REVIEW WELL KILL PROCEDURES 6/17/2012 00:00 - 06:00 6.00 KILLW P DECOMP WAIT ON DAY CREW TO KILL WELL - PERFORM RIG MAINTENANCE - CLEAN AND PAINT PROJECTS REVIEW WELL KILL PROCEDURES 06:00 - 07:30 1.50 KILLW P DECOMP WAIT ON DAY CREW TO KILL WELL PERFORM RIG MAINTENANCE - CLEAN AND PAINT PROJECTS - REVIEW WELL KILL PROCEDURES 07:30 - 08:30 1.00 KILLW P DECOMP REVIEW DOYON SAFETY EXPECTATIONS. - KNOWLEDGE AND APPLICATIONS. - FACILITATED BY CHECK 6. - PJSM. WELL KILL WITH ALL INVOLVED. - EMPHASIS ON COMMUNICATION AND STEP BY STEP REVIEW. 08:30 - 10:30 2.00 KILLW P DECOMP SITP = 1425 PSI SICP = 1475 PSI4)/A = 0 PSI -BLEED OF GAS OFF OF VA THRU CHOKE. - GOOD INDICATION OF LIQUID RETURNS AFTER 3 - 4 MINUTES. SICP AFTER BLEEDING GAS = 1325 PSI. SITP = 1200 PSI. - EQUALIZE PRESSURE WITH MUD PUMP AND OPEN TO WELL. - PUMP DOWN TUBING @ 3 BPM / 1900 PSI, HOLDING CASING PRESSURE CONSTANT. PUMPING 11.9 PPG BRINE. FCP 3 BPM 1400 PSI, (50 BBLS AWAY). - PUMP 50 BBLS, SHUT IN VA AND BULLHEAD 25 BBLS @ 3 BPM / 1700 PSI. - LINE UP TO TAKE RETURNS UP VA THRU CHOKE TO FLOW BACK TANK. - PUMP 4 BPM INITIALLY AND DECREASE PUMP RATE TO 2 BPM 875 PSI, 2000 PSI ON THE VA. I/A DROPPED BACK DOWN TO 1600 PSI AFTER PUMPING @ 2 BPM FOR A FEW MINUTES. - PUMP 200 BBLS AFTER BULL HEADING, SHUT DOWN AND CHECK TANK. - EMPTY TANK, (160 BBLS). 250 PUMPED, LOST 90 BBLS. 10:30 - 12:00 1.50 KILLW P DECOMP - RESUME PUMPING DOWN TUBING, 3 BPM / 800 PSI, VA 1325 PSI. - LEAK DISCOVERED IN PLUG VALVE ON HARD LINE TO FLOW BACK TANK. - (3) TABLESPOONS LEAKED TO SECONDARY CONTAINMENT. PLUG VALVE REMOVED. - PRESSURE TESTED HARD LINE, 250 / 3500 PSI, 5 MIN EACH, OK. Printed 7/9/2012 10:22:39AM Common Well Name: MPF -05 AFE No Event Type: WORKOVER (WO) Start Date: 6/16/2012 End Date: X4- 00WC0 -E (1,700,000.00 USD) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/29/1997 12:00:00AM Rig Release: 6/22/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @31.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 22:00 10.00 KILLW P DECOMP CONTINUE PUMPING A TOTAL OF 391 BBLS AFTER BULL HEADING. - CHECK TANK, 110 BBLS, LOST 81 ....TOTAL LOST 171 BBLS. - TAKE A SAMPLE, 11.93 PPG COMING BACK. SHUT DOWN. - BLEED OFF ALL PRESSURE AND SHUT IN. PRESSURE CLIMBED ON VA TO 152 PSI - BLEED OFF FOR (5) MINUTES, AND SHUT IN, CLIMBED TO 80 PSI. - BLEED OFF TBG AND VA FOR 7 MINUTES, (5) BBLS BACK AND SHUT IN. - PRESSURE CLIMBED TO 45 PSI. BLEED FOR (15) MINUTES, (4) BBLS BACK. - SHUT IN AND PRESSURE CLIMBED TO 30 PSI. BLEED TBG AND VA FOR (30) MINUTES, (3) BBLS BACK. SHUT IN FOR (30) MINUTES. SITP = 15, SICP 18 PSI. - DISCUSSED W/ ODE AND WTL. RECEIVED PERMISSION TO CONTINUE TO BLEED UNTIL NO FLOW / NO PRESSURE OR PRESSURE STABILIZES. NOTE: 171 BBLS LOST TO FORMATION DURING KILL. 19 BLED BACK. OBSERVE THAT SHUT IN PRESSURES CONTINUE TO DECREASE EACH TIME IT IS BLED OFF AND SHUT IN, ON 30 MINUTE INTERVALS - ALSO OBSERVE THAT FLOW AND BBLS DECREASED TO ZERO - REPEAT PROCESS UNTIL PRESSURES ARE "0" • - - UBING AND IA AND THERE IS 1 O FLOW TH SITP =0 SICP = 0 - MONITOR WELL FOR 30 MI TES - ELL IS STATIC 22:00 - 00:00 2.00 WHSUR P DECOMP PJS ' , = OW DO •WN LINES AND CHOKE - R/D KILL MANIFOLD AND RELATED LINES AND VALVES - R/U LINE TO FILL AND MONITOR IA - TOTAL 24 HOUR FLUID LOSS TO WELL = 150 BBLS 6/18/2012 00:00 - 01:30 1.50 WHSUR P DECOMP PJSM, SPCC CHECKS AND R/U LUBRICATOR - R/U LINES TO IA TO FILL AND MONITOR FLUID STATUS - R/U DSM LUBRICATOR AND M/U TO TREE 01:30 - 02:00 0.50 WHSUR P DECOMP TEST DSM LUBRICATOR - 250 PSI LOW, 3500 PSI HIGH, 5 MIN, CHARTED - GOOD TEST 02:00 - 02:30 0.50 WHSUR P DECOMP PJSM WITH DSM ON FALL PROTECTION WHILE ON STACK - DSM INSTALLED 2 9/16" TWO Printed 7/9/2012 10:22:39AM Y � Common Well Name: MPF -05 AFE No Event Type: WORKOVER (WO) Start Date: 6/16/2012 End Date: X4- 00WC0 -E (1,700,000.00 USD) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/29/1997 12:00:00AM Rig Release: 6/22/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table ©31.30ft (above Mean Sea Level) Date From - To Hrs (hr) Task Code NPT NPT (ft) Depth Phase Description of Operations 02:30 - 04:00 1.50 WHSUR P DECOMP TEST TWC FROM BELOW AND ABOVE - PERFORM ROLLING TEST FROM B BLS R ATE ELOW, 500 PSI 1 , 10 B IN , 570 CHARTED - - FINAL P PUMP OF PM M PSI P B TOTAL - BLEED OFF 6 UM BBLS ED BACK 27 P TO PITS 21 / EE TO W - TEST TWC FROM BBLS LOSS ABOVE , 250 CT PSI LOW, 4000 PSI HIGH, 5 MIN, CHARTED GOOD D TEST , R/D TEST - R/D DSM LUBRICATOR - R I LINES TO IA LINES FOR CONTINUOUS FILL, TO MONITOR FLUID LOSSES - ESTABLISH LOSS RATEOF9BPH 04:00 05:30 1.50 WHSUR P DECOMP PJ, / ADAPA - - 9 LH THREADS = GOOD FP REP ' INSPECTED TREE AND HANGER THREADS FL : - CHECKED TER LOCK DOWNS SCREWS -TWO BARRIFRS ARF KIII,. WT FLUID AND TESTED TWC IN HANGER 05:30 - 07:00 1.50 BOPSUR P DECOMP PJSM. N/U BOPE. - N Ul 13/ 5/8" X 5M BOPE. , FROM BOTTOM UP: 1/6" 5M X 135/8" 5M FLANGED ADAPTER. -27/8" X 5" VBRS, MUD CROSS, BLIND SHEAR RAMS, 2 7/8" X 5 VBRS AND ANNULAR PREVENTOR. 07:00 - 15:30 8.50 BOPSUR P DECOMP _RIG UP TO TEST BOPS, PJSM. TESTING W/ FRESH WATER. TEST ALL VALVES ON CHOKE MANIFOLD. - TEST BLIND SHEAR RAMS 250 / 4000 PSI ALL TESTS. - TEST VBRS W/ 4" & 2 7/8" TEST JTS, 250/4000 PSI, OK. - TEST MUD CROSS VALVES 250 / 4000 PSI. ALL TESTS 5 MIN EACH. - TEST ANNULAR PREVENTOR W/ 2 7/8" TEST JT, 250 / 3500 „7 PSI. - ALL TESTS CHARTED AND 5 MINUTES EACH, HIGH AND LOW. - PERFORM DRAWDOWN TEST ON ACCUMULATOR. - RIG DOWN TESTING EQUIPMENT. -WELL TAKING 5 BPH THROUGH JEFF JONES OF AOGCC WAIVED OUT STATES TESTING - RIGHT TO WITNESS 15:30 - 17:00 1.50 WHSUR P DECOMP PJSM. PRW CHECK VALVE. - DRAIN EPARE BOP TO STACK PULL T - O R/U WAY OPSO -LOPSO AND PU - 3 R/ 50 U LUBRICATOR 17:00 19:00 2.00 WHSUR P DECOMP TE LRC - E 250 MP PSI IN SUB LOW, 0 PSI HIGHST , 5 UB MIN, CHART D - PULL TWC - R/D LUBRICATOR I AND OPSO -LOPSO - WELL TOOK 3 BBLS TO FILL 19:00 - 20:30 1.50 WHSUR P DECOMP PJSM, ESP SHEAVE, TRUNK AND RELATED EQUIPMENT, DISCUSSED DROPPED OBJECTS AND MENTORING OF NEW HANDS LAY OUT HERCULITE AND MATS FOR ESP PATH - PREPARE EQUIPMENT TO PULL HANGER TO RIG FLOOR Printed 7/9/2012 10:22:39AM � �� f :. arc � . , 6 Common Well Name: MPF -05 AFE No Event Type: WORKOVER (WO) Start Date: 6/16/2012 End Date: X4- 00WC0 -E (1,700,000.00 USD) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/29/1997 12:00:00AM Rig Release: 6/22/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @31.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:30 - 22:00 1.50 WHSUR P DECOMP PJSM, PULL HANGER TO RIG FLOOR -M /U LANDING JT TO HANGER - CHECK FOR PRESSURE ON IA = 0 - FMC REP. BACKED OUT LOCK DOWN SCREWS - PULL HANGER OFF SEAT WITH 112K - PULL HANGER TO RIG FLOOR - PUWT = 105K, SOWT =79K (INCLUDES 40K BLOCK WT) - REMOVE ESP CABLE FROM HANGER - LAY DOWN HANGER AND LANDING JOINT W/ 3' PUP, AND 10 FOOT `PUP - PULL ONE SINGLE TO FIRST CLAMP - CUT ESP CABLE ABOVE SECURE CLAMP - LOWER SINGLE BACK IN HOLE SO THAT SLICK PIPE IS ACROSS BOP - CONSTANTLY MONITOR HOLE FOR GAIN / LOSS 22:00 - 00:00 PULL P DECOMP M /U,TIW AND HEAD PINTO 2 7/8" EUE 8RD - CLOSE RAMS, LINE UP TO TAKE RETURNS THROUGH GAS BUSTER - CIRCULATE 1 TUBING VOLUME, 50 BBLS - 3 BPM = 620 PSI - 11.9 PPG IN AND OUT, 5 BBL LOSS WHILE CIRCULATING - SPR'S, 2 BPM = 340 PSI, 3 BPM = 620 PSI - PUMPS OFF, BLEED OFF PSI, OPEN RAMS - MONITOR WELL 10 MINUTES = FLUID IS SLOWLY DROPPING IN BOP STACK - BLOW DOWN AND RIG DOWN ALL CIRULATING LINES - PREPARE RIG TO POOH - 24 HOUR FLUID LOSS = 119 BBLS 6/19/2012 00:00 - 00:30 0.50 PULL P DECOMP PJSM, SERVICE RIG, SPCC CHECKS - REVIEW SOP FOR POOH WITH ESP COMPLETION - REVIEW OPERATIONAL PROCEDURE OF SPOOLING UNIT 00:30 - 12:00 11.50 PULL P DECOMP BEGIN POOH WITH 2 7/8" 6.5# EUE 8RD ESP. COMPLETION STRING - PULL ESP CABLE OVER SHEAVE AND CONNECT TO SPOOLING UNIT - PUWT = 105K, SOWT =79K (INCLUDES 40K BLOCK WT) - MAINTAIN CONSTANT HOLE FILL WITH 11.9 KWF WHILE POOH - POOH FROM 8300' TO DISCHARGE HEAD AT 73' - OUT OF HOLE = 259 JOINTS, 2) 10' PUPS, 1) 2' PUP - 2 GLM ASSY, XN NIPPLE, AND ESP PUMP ASSY - RECOVERED: - 137 LASSALE CLAMPS - 5 PROTECTOLIZER CLAMPS - 3 FLAT BAR CLAMPS 12:00 - 14:00 2.00 PULL P DECOMP PJSM, LAYING DOWN ESP PUMP AND MOTOR ASSY - CUT ESP CABLE AND SECURE IN SPOOLING UNIT - UD ESP MOTOR AND PUMP ASSY 14:00 - 17:30 3.50 PULL P DECOMP R/D CENTRILIFT EQUIPMENT - CLEAR CLAMPS FROM FLOOR AND RELATED EQUIPMENT - R/D ESP SHEAVE - CLEAN RIG FLOOR - PERFORM WORK ORDERS 17:30 - 00:00 6.50 EVAL P DECOMP PJSM, M/U 7" CHAMP PACKER RIH WITH PACKER USING 2 7/8" 6.5# EUE 8RD TUBING - CHANGE OUT BAD JOINTS ON THE WAY IN - RIH F/ SURFACE T/ 5389' - PUWT = 78K, SOWT = 62K - OA = 0 PSI - 4 -5 BPH LOSS RATE WITH CONTINUOUS HOLE FILL. Printed 7/9/2012 10:22:39AM � iw % iu� ry : w _ ; z Common Well Name: MPF -05 AFE No Event Type: WORKOVER (WO) Start Date: 6/16/2012 End Date: X4 (1,700,000.00 USD) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/29/1997 12:00:00AM Rig Release. - OOWCO -E 6 /22!2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @31.30ft (above Mean Sea Level) Date From - To Firs Task Code NPT NPT Depth Phase Description TU of Operations (hr) (ft) 6/20/2012 00:00 - 05:00 5.00 EVAL P DECOMP CONTINUE RIH WITH CHAMP PACKER ON 2 7/8" EUE 8RD BING :I( RIH WITH 7" CHAMP PA F/ 5389' T/ 400' MAINTAIN CONSTANT HOLE FILL WITH 11.9 WF WHILE RIH - PUWT = 86K, SOWT = 74K CKER CIRCULATE AT 4BPM = 1040 PSI PUMPS OFF, S T .. ' _ _ I' 05:00 - 06:00 1.00 EVAL P DECOMP ` , T - R/U PJSM TEST HOSES AD PURGE CLOSE UPPER PIP CASING E N RAMS - MIT -IA TO 2500 PSI 30 MII Ir) - PUPED EST 23 STOKES. 0' PSI OUG PERFORM MON MI T -IA D PER t,' ( HARTF - REPORT PASS EQ RINTHE TEST. TL AND TO W RECEIVED APPROVAL TO RUN COMPLETION. WEL E T '0' Y - OPEN SL V UPPER RIFY AL PIPE PR RAMS AND SSURE CONFIRM B CIRCULATING —3 BBLS KWF. UNSET TEST TOOL PER HES REP. BLOW DOWN LINES =T NLE , LOSS A COMPLETED FOR —5 BPH. WELL STAR WORK CONTI TRANSFER UOUS PERMIT T MPF - 96 . HO 06:00 - 06:15 0.25 EVAL ` P DECOMP P/U 1 4" D RIH TO 8423 P. D ' M 06:30 0.25 06:30 - 08:00 1.5 EVAL P DECOMP PJSM ON CUT AND SLIP DRILLING LINE. NIT. EVAL P 06:15 DECOMP CUT AND 62' DRILLING LINE. - SERVICE DRAWORKS. 08:00 - 09:00 1.00 EVAL P DECOMP LID 4" DP. INSPECT SAVER SUB ON TOP DRIVE UNIT. - CHANGE OUT HI LO DRUM C HANDLE BLOW DOWN T 6' MD. OP DRIVE. 09:00 12:00 3.00 EVAL P DECOMP PJSM, POH F/ 9400' MD WITH 7" CHAMP PACK T 527 - L/D 12 JTS 2 -7/8" TBG TO PIPE LUTCH SHED 1X1. THEN STAND BACK IN DERRICK MAINTAIN ER O/ CONTINUOUS HOLE FILL WITH 11.9 # BRINE. - AT -4 BPH LOSS RATE. i i L OST FOR 63 BBLS LAST RE -TOUR 12 FIRS. 12:00 - 12:30 0.50 EVAL P DECOMP 12:30 - 16:30 4.00 EVAL P ERM P PJSM ON POH. DECOMP CONTINUE POH FROM 5267 CHECKS ' MD W/ 7" CHAMP PACKER. - MAINTAIN CONTINUOUS HOLE 11.9 # BRINE. -AT'-4 BPH LOSS RATE. - CONTROL SWABBING BY MONITORI WITH NG TRIP SPEED. - L/D CHAMP PACKER 16:30 - 17:30 1.00 BOPSUR P DECOMP CLEAR RIG FLOOR - PULL WEAR RING - MONITOR LOSS RATE _ —2.5 BPH Printed 7/9/2012 10:22:39AM . a s Common Well Name: MPF -05 AFE No Event Type: WORKOVER (WO) Start Date: 6/16/2012 End Date: X4 -OOWCO E (1,700,000.00 USD) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/29/1997 12:00:00AM Rig Release: 6/22/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @31.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:30 19:00 1.50 RUNCOM P RUNCMP PJSM, R/U FLOOR TO RUN COMPLETION - MOBILIZE CLAMPS AND EQUIP TO RIG FLOOR - HANG ESP CABLE SHEAVE - STING ROPE THROUGH SHEAVE TO SPOOLING UNIT 19:00 23:00 4.00 RUNCOM P RUNCMP PJSM, M/l l FSP PIMP AM') FOI IIPMFNT - M/U CL -6 KMH 190 HP MOTOR AND PUMP ASSY PER CENTRILIFT REP STRING CABLE TO RIG FLOOR - ATTACH ESP CABLE AND TEST SAME - INSTALL 6 PROTECTOLIZER CLAMPS ON PUMP / MOTOR ASSY - INSTALL 3 ARMSTER GUARDS INSTALL 2 HALF CLAMPS - PERFORM CONDUCTIVITY TEST = GOOD TEST 23:00 - 23:30 0.50 RUNCOM P RUNCMP HOLD WELL CONTROL DRILL WITH NON- SHEARABLES ACROSS BOP STACK - HOLD AAR WITH RIG CREW, CENTRILIFT HAND AND WSL DISCUSSED DIFFERENT PROBLEMS AND SCENARIOS THAT MAY OCCUR AND WHAT TO DO ABOUT THEM - DISCUSSED ACCUMULATOR FAILURE PROCEDURES - NEED TO KNOW ROLES AND RESPONSIBILITIES OF ALL POSITIONS - MENTORING OF NEW HANDS 23:30 - 00:00 0.50 RUNCOM P RUNCMP CLEAN RIG FLOOR OA = 0 PSi - 24 HOUR FLUID LOSS = 106 BBLS 6/21/2012 00:00 - 00:30 0.50 RUNCOM P RUNCMP SERVICE RIG AND SPCC CHECKS - INSPECT RIG UP FOR RIH W/ COMPLETION - INSPECT SPOOLING UNIT AND SHEAVE TIE OFF - INSPECT TONGS AND HANDLING EQUIP 00:30 - 03:00 2.50 RUNCOM P RUNCMP PJSM, RUNNING ESP COMPLETIQN__ - RIH W /2718"6.5#EUE8RDESP COMPLETION PER RUNNING ORDER - RIH F/ 71' T/ 1000' - CHECK CONTINUITY AT 1000', THEN EVERY 2000' THEREAFTER - BRAKE CIRCULATION .5 BPM = 510 PSI Printed 7/9/2012 10:22:39AM • t Common Well Name: MPF -05 AFE No Event Type: WORKOVER (WO) Start Date: 6/16/2012 End Date: X4- 00WC0 -E (1,700,000.00 USD) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/29/1997 12:00:00AM Rig Release: 6/22/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @31.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:00 - 05:00 2.00 RUNCOM P RUNCMP H2S GAS ALARM ACTIVATED - ALL HANDS QUICKLY ASSEMBLED AT THE MUSTER AREA - THE PAD WAS BLOCKED OFF AND ALL SERVICE HANDS WERE NOTIFIED - DRILLER AND FLOORHAND DONNED SCOTT AIR PACKS AND NOTED THAT ALL INDICATORS WERE READING ZERO AS THEY EXITED THE RIG FOR THE MUSTER AREA NOTIFICATIONS WERE MADE TO RWO SUPERVISOR AS WELL AS DOYON DRILLING SUPERINTENDENT AND SAFETY SUPERVISOR AUTHORIZATION TO RE -ENTER PER DOYON PROCEDURE WAS OBTAINED - RE -ENTRY WAS MADE AND RIG WAS PRONOUNCED "ALL CLEAR" - HANDS RETURNED TO THE RIG SAFELY - AAR WAS CONDUCTED WITH CREW, TOUR PUSHER AND WSL - RIG ELECTRICIAN WAS CALLED OUT TO EVALUATE AND TEST ALARM SYSTEM BEFORE PROCEEDING 05:00 - 07:00 2.00 RUNCOM P RUNCMP CONTINUED RIH W/ 2 7/8" 6.5# EUE 8RD ESP COMPLETION - RIH F/ 1000' T/ 2523' MD - INSTALL CANNON CLAMPS EVERY OTHER JOINT TO SURFACE - BREAK CIRCULATION EVERY 2000' AND CHECK CONDUCTIVITY - ENSURE CONTINUOUS HOLE FILL WHILE RIH - LOSS RATE = —3 - 4 BPH 07:00 - 12:00 5.00 RUNCOM N RREP 2,523.00 RUNCMP DERRICKMAN REPORTED THAT THE TOP DRIVE WAS TRAVELING OUT OF ALIGNMENT. - THE DERRICKMAN CAME DOWN AND INSPECTED THE TOP DRIVE, FINDING THE UPPER ROLLER ASSEMBLY , DISENGAGED FROM THE TORQUE TUBE. - ONE OF THE BOLTS HAD BROKEN, THAT SECURES THE TORQUE TUBE ROLLER ASSEMBLY IN PLACE. - UPPER OFF DRILLER SIDE. - THE BOLT WAS SECURED IN PLACE WITH IT'S SAFETY WIRE. - NO DROPPED OBJECT OCCURRED. - REFER TO IR- 4160293 - — 3 BPH LOSS RATE DURING THIS TASK. 12:00 - 12:30 0.50 RUNCOM P RUNCMP - PERFORM TOP DRIVE INSPECTION. - PERFORM PRE -TOUR CHECKS. 12:30 - 13:00 0.50 RUNCOM P RUNCMP PJSM RUN ESP COMPLETION ON TBG FROM DERRICK. Printed 7/9/2012 10:22:39AM Common Well Name: MPF -05 AFE No Event Type: WORKOVER (WO) Start Date: 6/16/2012 End Date: X4- OOWCO -E (1,700,000.00 USD) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/29/1997 12:00:00AM Rig Release: 6/22/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @31.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:00 - 20:00 7.00 RUNCOM P RUNCMP CONTINUE RIH F/ 2523' MD T/ 7089' W/ 2 -7/8" ESP COMPLETION FROM DERRICK. - INSTALL S EV OTHER JOINT TO SURFA CE - RAN ONE ADDITIONAL CLAMP ON ERY JT #78 TO C.8 . O' MD. - BREAK OVER 4 CIRCU DG EVERY LEG AT 2000 AND CHECK CONDUCTIVITY - 1/2 BPM = 760 PSI. ENSURE CONTINUOUS HOLE FILL WHILE RIH - LOSS RATE _ -3 WTL AND RWO SUPERINTENDENT VISITED THE RIG AND QUIZZED THE CREW ON WELL CONTROL. INSPECTED CELLAR CHOKE MANIFOLD, KOOMY UNIT AND FLOW BACK TANK. - 20:00 - 22:00 2.00 RUNCOM P - RUNCMP PERFORM SPLI' - CHECK CONDUCTIVITESP CABLE Y, GOCE OD AT TEST 7089 22:00 - 00:00 2.00 RUNCOM P RUNCMP ' RIH F/ 70 T/ 8227' PUWT 95K, SOWT = 80K. INCLUDES TOP DRIVE 0K - OA =OPSi - 24 HOUR FLUID LOSS = 112 BBLS 6/22/2012 00:00 - 01:00 1.00 RUNCOM P RUNCMP SERVICE RIG AND SPCC CHECKS - ENSURE GOOD CHANGE OUT WITH RELIEF - PJSM FOR LANDING HANGER - P/U LANDING JT AND M/U TO HANGER - M/U HANGER TO STRING W/ FMC REP PRESENT 01:00 - 02:30 1.50 RUNCOM P RUNCMP IN TERMINATE ENSTALL PETR ESP A CABLE TOR IN HANGER - - TEST CONDUCTIVITY = GOOD TEST 02:30 - 03:00 0.50 RUNCOM P RUNCMP SUCK OUT STACK PUWT = 95K, INCLUDES 40K SOWT D B = 80K, TOP DNLO WT - LAND RIVE TUBING A HANGER - MOTOR DEPTH = 8253.36 - CLAMPS USED: - SINGLES = 2 - PROTECTOLIZERS = 6 - ARMSTER = 3 - CANNON = 138 03:00 - 03:30 0.50 WHSUR P -_ RUNCMP FMC VERIFY LOCATION SET OF HANGER - RUN IN LOCK DOWN SCREWS 03:30 - 04:00 0.50 WHSUR P -_ RUNCMP UDN LANDING JOINT AND CROSSOVERS - INSTALL TWC 04:00 - 05:00 1.00 WHSUR P RUNCMP TEST TWC FROM BELOW WITH ROLLING TEST - 500 PSI, 10 MIN, CHARTED, FCP = 560 PSI @ 1 BPM - 13 BBL LOSS DURING ROLLING TEST - TEST TWC FRO ABOVE, 250 PSI LOW, 3500 PSI HIGH, 5 MIN, CHARTED - GOOD TESTS, R/D TEST EQUIPMENT Printed 7/9/2012 10:22:39AM ti ., � _ 4 ' m Common Well Name: MPF -05 AFE No Event Type: WORKOVER (WO) Start Date: 6/16/2012 End Date: X4 -OOW E (1,700, USD) Project: Milne Point Site: MD Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/29/1997 12:00:00AM Rig Release: CO 6/22/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @31 .30ft (above Mean a Level) Date From - To Hrs Task Code Se NPT NPT Depth Phase Description of Operations (hr) (ft) 05:00 - 05:30 0.50 BOPSUR P RUNCMP PJSM, BLOW D 05:30 - 07:30 OWN ALL SURFACE LINES. - MAINTAIN CONTINUOUS HOLE FILL -11.9 ND PPG BOPS N BRINE AT —3 BPH LOSS RAFILL TE. 2.00 BOPSUR P RUNCMP PJSM, VOID BOP STACK OF KWF. - - MAINTAI CONTINUOUS HOLE HRS N G TO CHUCK SCV AT 0715 HRS OTICE 6/22/12 OF BOPS CHU TEST ON MPF - -24 96. 07:30 08:00 0.50 WHSUR P RUNCMP CENTRILIFT REP CHECK IVEN CONDUCTIVITY HE OF E ESP'PENITRATORS. -PASSED. / VOID. WEEKL Y CREW CHAINSPECT NGE TBG AT 0800 HRS 08:00 10:00 2.00 WHSUR P RUNCMP PJSM N/U 11'X 7 -1/16 "ADAPTER HANGER FLANGE A- ND FMC 2- 9/16" PRODUCTION TREE. - PER FMC REP. 10:00 - 12:00 2.00 WHSUR P RUNCMP FMG REP PRESSURE TESTED HANGER VOID TO OW R AR MINUTE L S. / 5000 PRESSURE TESTED TREE TO 250 LOW AND 3500 PSI FOR 5 CHARTED PSI MINUTES. CENTRILIFT TAKE FINAL FO READING. 30 TED CH 12:00 13:30 1.50 WHSUR P RUNCMP INSTALL 1502 FLANGE ON TREE WING VALVE. PJSM - M/U WELL SUPPORT LUBRICATOR TREE. - PRESSURE TEST LUBRICATOR TO 250 LOW / 3500 PSI FOR 5 CHARTED MINUTES. - PULL TWC. 13:30 - 16:00 2.50 WHSUR P RUNCMP PRESSURE TEST LUBRICATOR 250 LOW TO / 3500 FOR 5 CHARTED MINUTES. - INSTALL 2 1/2" TYP'H' BPV. AND -OVER FOR PERFORM FACE TO FACE H NEXT WELL L WITH MPU WELL OPS COORDINATOR ON PF -96 16:00 - 17:00 1.00 WHSUR P RUNCMP PERFL BELO THE BPV - 1.5 BPM / 500 - 600 ING PSI TEST FOR 10 FROM CHARED MINUTES. ORM - RD LUBRICATOR - RID BLOW DOWN ALL CELLAR LINES FINISH CLEAN PITS 17:00 - 18:00 1.00 WHSUR P RUNCMP SECURE TREE VALVES. -RIG RELEASED AT 1800 HRS 6/22/12 FOR MOVE TO MPF -96 Printed 7/9/2012 10:22:39AM A Tree: Cameron 2 9/16" 5M F-05 Wellhead: 1 1 " x 7 1/16" 5M MPU F -05 Orig.Orig. lev. = 41.3' (N 22E) Elev. = 12.3' Gen 5A, w/ 2 7/8" FMC tbg. hng., 3" - RT To Csg.. Spool = 27.5' (N 22E) LH acme on top and 2 7/8" EUE 8 rd on bottom, 2.5" CIW BPV profile ) 20" 91.1 ppf, H -40 112' 2 7/8" x 1" KBMG -M -2 GLM I r' W/ DPSOV 138 KOP @ 2,000' Max. hole angle = 61 deg. @ 5220' Hole angle thru' perfs = > 1 deg. c 9 5/8" ES Cementer 1 2006' and 9 5/8 ", 40 ppf, L - 80 Btrc. 5,570' 1 1 2 7/8" x 1" KBMG -M -2 GLM I 7,996' I w/ DGLV 7" 26 ppf, L -80, Mod. Btrc. prod. csg. ( drift ID = 6.151 ", cap. = 0.0383 bpf ) ,4 HES XN - Nipple 2 -7/8" 8rd. I 8,149' I 2 7/8" 6.5 ppf, L -80, 8 rd EUE tbg.. (2.250" id) ( drift ID = 2.347 ", cap. = 0.00592 bpf) 4 WeIILift Discharge Gauge Unit 8,190' / Centrilift Pump, 137 -P17 SXD Pump 8,195' Centrilift Gas Separator GRSFTX I 8,214' Tandem Seal Section GSB3DB UT /LT SB /SB PFSA CL6 8,219' OULFia Two 7" x 21' marker jts. orhis f/ 8273' - 8314' RKB MEM Motor, 190 HP, 2415 volt, 48 amp 8,233' Stimulation Summary aw Model KMH Mff 05/23/97 - 144,945 lbs. 16 -20 behind pipe Perforation Summary Ref to GR /CCL 05/17/97 WeIILift MGU / Centralizer 8,249' g 1 12/ Size SPF Interval (ND) (...( 3 3/8" 6 8,460' - 8,472' * 7,023' - 7,035' W.'" + y J } \ 3 3/8" 6 8,478' - 8,498' (7042' - 7062') V- 1 3 3/8" 6 8,503' - 8,523' * 7,066' - 7,086' S" iy) *3 3/8" PJ HSD 6 SPF 60 deg. phasing (Add Perfs) L� sL :2: Q �.P� 22.5 RDX bighole charges ,ll[�' (EHD = 0.56 ", 12.89" TTP) ill U II ■ 7" float collar (PBTD) I 8,797' I 7" float shoe I 8,880' I DATE REV. BY COMMENTS MILNE POINT UNIT 5/24/97 JBF Initial ESP Completion by Nabors 4ES WELL No : F -05 7/7/97 M. Linder ESP RWO 4 -ES / 12/99 / 2/00 / 6/12 API : 50- 029 -22762 05/30/05 MDO ESP RWO 4 -ES Remove screens / Add perfs 6/28/12 AAR ESP RWO by Doyon 16 BP EXPLORATION (AK) .+-d.. .:.r ;s.:. — ar` "'.:'.:"r:AP:arxea � ; ".f, ^ .x n . , ._ ,_Y m s�,¢Fru.±r., µ °'?Au + : • " . . .. . x:,^. • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 Sit i FEE 1 Z012. i -1 �O 7 �f Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 114 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPF -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPF -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator is • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) MPF -Pad 10/29/2011 Corrosion Initial top of Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement Vol. of cement pumped cement date inhibitor sealant date ft bbls ft gal MPF -01 1950450 50029225520000 10.2 N/A 10.2 N/A 122.4 8/7/2011 MPF-02 1960700 50029226730000 4 N/A 4 N/A 35.7 8/8/2011 ---)P MPF -05 1970740 50029227620000 1.3 N/A 1.3 N/A 13.6 8/9/2011 MPF-06 1960020 50029226390000 1.2 N/A 1.2 N/A 15.3 8/2/2011 MPF-09 1971040 50029227730000 5.0 N/A 5.0 N/A 54.4 8/9/2011 MPF -10 1960940 50029226790000 1.7 N/A 1.7 N/A 20.4 8/212011 MPF -13 1950270 50029225490000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -14 1952120 50029226360000 0.1 N/A 0.1 N/A 8.5 10/6/2011 MPF -17 1971960 50029228230000 4.1 N/A 4.1 N/A 37.4 8/6/2011 MPF -18 1961000 50029226810000 8.3 N/A 8.3 N/A 91.8 8/2/2011 MPF -21 1961350 50029226940000 1.8 N/A 1.8 N/A 15.3 8/6/2011 MPF -22 1952010 50029226320000 4 WA 4 N/A 13.6 8/1/2011 MPF -25 1950160 50029225460000 0.3 N/A 0.3 N/A 6.8 10/29/2011 MPF -26 1970840 50029227670000 1.8 N/A 1.8 N/A 11.9 8/1/2011 MPF -29 1961170 50029226880000 6.7 N/A 6.7 N/A 56.1 8/9/2011 MPF -30 1951840 50029226230000 0.8 N/A 0.8 N/A 6.8 8/1/2011 MPF-33 2010620 50029226890000 23 Need top lob MPF-34 1971970 50029228240000 4.1 N/A 4.1 N/A 13.6 8/1/2011 MPF -37 1950250 50029225480000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -38 1951680 50029226140000 0.3 N/A 0.3 N/A 6.8 10/5/2011 MPF -41 1970950 50029227700000 0.8 N/A 0.8 N/A 8.5 8/9/2011 MPF -42 1970200 50029227410000 1.8 N/A 1.8 N/A 13.6 8/1/2011 MPF-45 1950580 50029225560000 8 N/A 8 N/A 78.2 8/11/2011 MPF-46 1940270 50029224500000 Sealed Conductor N/A WA N/A N/A N/A MPF-49 1970030 50029227320000 2.3 N/A 2.3 N/A 18.7 8/11/2011 MPF -50 1970580 50029227560000 1.7 N/A 1.7 N/A 6.8 7/31/2011 MPF -53 1951080 50029225780000 2.8 N/A 2.8 N/A 11.9 9/19/2011 MPF -54 1961920 50029227260000 1.7 N/A 1.7 N/A 10.2 8/1/2011 MPF -57A 2031670 50029227470100 1.3 N/A 1.3 N/A 13.6 8/11/2011 MPF -58 1961560 50029227060000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF-61 1951170 50029225820000 62 Need top fob MPF -62 1951610 50029226090000 2.0 NN 2.0 N/A 13.6 9/1/2011 MPF -65 1970490 50029227520000 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -66A 1961620 50029226970100 0.8 N/A 0.8 N/A 8.5 7/31/2011 MPF-69 1951250 50029225860000 0.8 N/A 0.8 N/A 8.5 8/4/2011 MPF -70 1951530 50029226030000 1.7 N/A 1.7 N/A 15.3 7/31/2011 MPF -73A 2001980 50029227440100 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -74 1961080 50029226820000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF -77 1951360 50029225940000 0.2 N/A 0.2 N/A 6.8 10/5/2011 MPF -78 1951440 50029225990000 0.7 N/A 0.7 N/A 5.1 7/31/2011 MPF -79 1971800 50029228130000 0.6 N/A 0.6 N/A 6.8 8/3/2011 MPF-80 1982170 50029229280000 0.5 N/A 0.5 N/A 3.4 8/3/2011 MPF -81 2000660 50029229590000 0.9 N/A 0.9 N/A 8.5 8/3/2011 MPF-82 2091350 50029229710000 1.7 N/A 1.7 N/A 15.3 8/3/2011 MPF-83 2000930 50029229630000 12 N/A 1.2 N/A 13.6 8/3/2011 MPF -849 2001760 50029229310200 1.2 N/A 1.2 WA 10.2 8/3/2011 MPF-85 1982500 50029229360000 0.1 N/A 0.1 N/A 7.7 9/1/2011 MPF -86 2010870 50029230180000 0.8 N/A 0.8 N/A 6.8 8/12/2011 MPF -87A 2032130 50029231840100 1.3 N/A 1.3 N/A 11.9 8/13/2011 MPF-88 2031930 50029231850000 1.3 N/A 1.3 WA 15.3 8/3/2011 MPF -89 2050900 50029232680000 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF -90 2012110 50029230510000 1.8 N/A 1.8 N/A 18.7 8/3/2011 MPF -91 2051100 50029232710000 1.7 N/A 1.7 N/A 11.9 8/13/2011 MPF -92 1981930 50029229240000 0.8 N/A 0.8 N/A 5.1 8/13/2011 MPF -93 2050870 50029232660000 0.3 N/A 0.3 N/A 7.7 9/1/2011 MPF -94 2011700 50029230400000 1.8 N/A 1.8 N/A 13.6 8/13/2011 MPF -95 1981790 50029229180000 0.5 N/A 0.5 N/A 3.4 8/13/2011 MPF -96 2081860 50029234060000 0.1 N/A 0.1 N/A 6.0 9/1/2011 MPF -99 2061560 50029233320000 1.3 N/A 1.3 N/A 11.9 8/11/2011 1 el ) STATE OF ALASKA-) ALASKA lAL AND GAS CONSERVATION COh,IIJlISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: D Abandon D Alter Casing D Change Approved Program Remove Screens D Suspend D Operation Shutdown 181 Perforate 181 Other 181 Repair Well D Plug Perforations D Stimulate D Re-Enter Suspended Well 181 Pull Tubing D Perforate New Pool D Waiver D Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 41.30' 8. Property Designation: ADL 388235 11. Present well condition summary Total depth: measured 8895 true vertical 7459 Effective depth: measured 8797 true vertical 7361 Casing Length Structural Conductor 78' Surface 5538' Intermediate Production 8853' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 4. Current Well Class: 181 Development D Exploratory o Stratigraphic D Service 5. Permit To Drill Number: 197-074 6. API Number: 50-029-22762-00-00 99519-6612 9. Well Name and Number: M PF-05 10. Field 1 Pool(s): Milne Point Unit 1 Kuparuk River Sands feet feet Plugs (measured) N/A feet Junk (measured) N/A feet Size MD TVD Burst Collapse 20" 112' 112' 1490 470 9-5/8" 5570' 4576' 5750 3090 7" 8880' 7444' 7240 5410 "~EP' JUL 0 tit 20D5 SCAN¡ )J 8460' - 8523' 7024' - 7087' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): 2-7/8",6.5# L-80 8300' None RBDMS 8FL JUN 3 0 2005 rc::~ r (""\\ F.. n f F"" a~ ~ =u \ ,'-"~ r;' ~,~ r¡~":n:I'.·.'l '\ !l""" ~~~ !i",.~,' 'ty [1,"'"" Treatment description including volumes used and final pressure: 13. Oil-Bbl Prior to well operation: 330 Subsequent to operation: 330 14. Attachments: D Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram JUN 2 9 2005 !'! ," ')'!:' ,". . I~,i'" as I{ ~\ ~ i \'~J "'"I r "', ,.... '",,;, ,.. ". ,1" """ Ië. . L.. ..,' Itllt : Representative Daily Average Production/~\~~~~ Data Gas-Met Water-Bbl Casino Pressure 131 310 0 142 331 340 Tubino Pressure o 313 15. Well Class after proposed work: o Exploratory 181 Development 0 Service 16. Well Status after proposed work: 181 Oil D Gas 0 WAG 0 GINJ D WINJ D WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 Printed Name Sondra Stewman Si9~~~~ Form 10-40 eVlsed 04/2004 - Title Technical Assistant Phone Prepared By Name/Number: DateCXv·-z.g·'l5Esondra Stewman, 564-4750 Submit Original Only 564-4750 Tree: Cameron 2 9/16" 5M . Wellhead: 11" x 7 1/16" 5M t Gen 5A, w/2 7/8" FMC tbg. hng., 3" LH acme on top and 27/8" EUE 8 rd on bottom, 2.5" CIW BPV profile I~ 20" 91.1 ppf, H-40 I 112' KOP @ 2,000' Max. hole angle = 61 deg. @ 5220' Hole angle thru' perfs = > 1 deg. 95/8",40 ppf, L-80 Btrc. I 5,570' I ~ 7" 26 ppf, L-80, Mod. Btrc. prod. csg. (drift 10 = 6.151", cap. = 0.0383 bpf) 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg.. ( drift 10 = 2.347", cap. = 0.00592 bpf) Two 7" x 21' marker jts. fl 8273' - 8314' RKB Stimulation Summary 05/23/97 - 144,945Ibs. 16-20 behind pipe Perforation Summary Ref log: GR/CCL 05/17/97 Size SPF Interval (TVD) 33/8" 6 8,460' - 8,472' * 7,023' - 7,035' 33/8" 6 8,478' - 8,498' (7042' - 7062') 3 3/8" 6 8,503' - 8,523' * 7,066' - 7,086' * 3 3/8" PJ HSD 6 spf 60 deg. phasing (Add Perfs) = 22.5 RDX bighole charges (EHD = 0.56",12.89" TIP) MPU F-05 .4 Orig "<.B"B Elev. = 41.3 ' (N 22E) OrÏl ).. Elev. = 12.3' RT ~To Csg.. Spool = 27.5 ' (N 22E) Camco 2 7/8" x 1" side pocket KBMM GLM () 9 5/8" ES Cementer i Camco 2 7/8" x 1" side pocket KBMM GLM HES XN-Nipple 2-7/8" 8rd. (2.205" id) Centrilift Pump, 151 8tg. GC1700 Model- GPMTAR 1:1 Centrilift Gas Separator GRSFTXARH6 ( 400 internals ) Tandem Seal Section Upper GSB3DBUTAB/HSNPFSA Lower GSB3DBL TAB/HSNFSACL5 Motor, 190 HP, 2415 volt, 48 amp Model KMH Phoenix MS-1 w/6 fin Centralizer = ~ 7" float collar (PBTO) 7"floatshoe DATE REV. BY COMMENTS 5/24/97 JBF Initial ESP Completion by Nabors 4ES 7/7/97 M. Linder ESP RWO 4-ES /12/99/2/00 /6/12 05/30/05 MDO ESP RWO 4-es Remove screens / Add perfs I 138' I I 2006' md 8,087' 8,227' I 8,244' 8,261' 8,266' 8,280' 8,300' 8,797' 8.880' MILNE POINT UNIT WELL No : F-05 API : 50-029-22762 Rp FXP~ ORATION (AK) ) ') BP AMOCO Operatiol1sSummary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 5/27/2005 5/28/2005 5/29/2005 PJSM. RID rig & equip. Scope down & lower derrick. Move from MPF-50 to MPF-05. Finish move to MPF-5. Finsh Laying out herculite & matting boards. Spot rig over well. Spot in pits & pipe shed. Con't to R/U equip. Raise & scope up derrick. Accepted rig @ 0200 hrs. Con't to R/U. R/U lines to tigertank & tree. DECOMP P/U lubricator & pull BPV. UD BPV & lubricator. DECOMP Take on Kill Fluid. Reclaiming fluid from previous well & having to filter & adjust weight to 10.5 ppg for kill. Test lines, OK. SICP = 1510 psi, SITP = 1430 psi, OIA = 0 psi. DECOMP PJSM. Discuss kill ops & proximity of well pad buidlings wI regard to gas venting. Alert pad operator. DECOMP Commence pumping 10.5 ppg brine around, taking mostly gas returns thru choke to tiger tank. Pump (1) tubing volume & bullhead 15 bbls @ 3 bpm I 1400 psi. Resume pumping down tubing @ 3 bpm I 1100 psi, taking mostly gas returns to tiger tank. WI 350 bbls pumped, begin seeing fluid back. Pump 400 bbls, see solid brine returns, bleed all pressure & shut in to monitor. DECOMP Monitor well. SITP = 350 psi. Order 11.7 ppg sodium bromide from mud plant, (600 bbls). DECOMP Wait on weighted brine. Empty tiger tank & pump remaining 10.5 brine around, shut in & monitor well. SITP = 290 psi, SICP = 300 psi. DECOMP Empty tiger tank. Wait on Fluid, then take on 2nd load of 11.7 ppg kill fluid. Monitor well. DECOMP Open well. SITP 300 psi, SICP 310 psi. Circulate @ 3 BPM, 560 psi. Pumped 300 bbls. SID & open into pits. Pump additional 60 bbls. Had 11.7 ppg returns. SID pump & monitor well. Well dead. While circulating last 60 bbls losses were 4 bbls in 10 min. Set & test TWC to 3500 psi. N/D tree & HCR valve. N/U 2nd annular valve. N/U BOPE & adapter flange. Con't to N/U BOPE & adapter flange. Repair choke in choke manifold. DECOMP Pressure test BOPE as per BP/AOGCC requirements. LP 250 psi, HP 3500 psi. BOP test witnessing waived by John Crisp wI AOGCC. Test witnessed by BP rep Tom Abbott & Tour Pusher Steve Bounds. DECOMP Clear rig floor. BOLDs. DECOMP PJSM. Pull hanger to floor, broke free @ 80K, stable up wt of 72K. Test & UD hanger. DECOMP PJSM. Line up & circulate heated brine, (1) hole volume @ 5 bpm I 1300 psi. (13) bbls to fill hole. Loss rate while circulating = 8 bbls I hour. DECOMP PJSM. POOH w/2 7/8" ESP completion string. Well stable. Calculated hole fill = 30 bbls, actual = 60 bbls. DECOMP UD & inspect ESP assembly. DECOMP Clear & clean rig floor. DECOMP ,Remove elephant trunk & ESP tools. R/U to P/U 31/2" DP. I I MPF-05 MPF-05 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES From - To Hours Task Code NPT Phase 19:00 - 21 :00 2.00 RIGD P 21 :00 - 00:00 3.00 MOB P 00:00 - 00:30 0.50 MOB 00:30 - 02:00 1.50 RIGU 02:00 - 03:00 1.00 RIGU 03:00 - 04:00 1.00 WHSUR 04:00 - 07:00 3.00 KILL 07:00 - 07:30 0.50 KILL 07:30 - 10:30 3.00 KILL PRE PRE PRE PRE PRE 10:30 - 11 :00 0.50 KILL 11 :00 - 18:00 7.00 KILL 18:00 - 19:30 1.50 KILL 19:30 - 22:00 2.50 KILL 22:00 - 22:30 22:30 - 23:30 23:30 - 00:00 00:00 - 02:00 DECOMP DECOMP DECOMP DECOMP 0.50 WHSUR 1.00 WHSUR 0.50 BOPSUR 2.00 BOPSUF P 02:00 - 06:30 4.50 BOPSUR P 06:30 - 07:00 0.50 BOPSUP P 07:00 - 08:30 1.50 PULL P 08:30 - 10:00 1.50 PULL P 10:00 - 15:30 5.50 PULL P 15:30 - 17:30 2.00 PULL P 17:30 - 18:00 0.50 PULL P 18:00 - 19:00 1.00 PULL P Page 1 of 3 Start: 5/27/2005 Rig Release: 6/1/2005 Rig Number: Spud Date: 4/29/1997 End: 6/1/2005 Description of Operations Printed: 6/6/2005 11 :22:07 AM ) ) BP AMOCO Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-05 MPF-05 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/27/2005 Rig Release: 6/1/2005 Rig Number: Spud Date: 4/29/1997 End: 6/1/2005 5/29/2005 19:00 - 19:30 0.50 PULL P DECOMP Hold PJSM. P/U halliburton screen retreiving tool. M/U on 3 1/2" DP. 19:30 - 22:00 2.50 PULL P DECOMP P/U 3 1/2" DP 1 x1 & RIH. 22:00 - 22:30 0.50 PULL P DECOMP Service rig & adjust brakes. 22:30 - 00:00 1.50 PULL P DECOMP Con't to P/U 3 1/2" DP 1 x1 & RIH wI Retreiving tool. 5/30/2005 00:00 - 02:00 2.00 PULL P DECOMP Can't to P/U 3 12/" DP 1 x1 & RIH wI retreiving tool. Ran 264 jts to 8368'. 02:00 - 04:30 2.50 PULL P DECOMP P/U kelly & break circulation. P/U wt = 122K, S/O wt = 85K. 3 BPM @ 1000 psi. Tag up on packer & screen assy @ 8376'. Slack off wI 20K & shear tool. P/U & shear out packer wI 25K over pull. Con't to P/U to 175k & packer came free. Allow rubbers to relax. Attempt to circulate bottoms up. Screen assy appears to be packed off. Lost 22 bbls in 8 min of circulating. Attempt to POH. Packer is swabbing. Have piston effect when working pipe. Attempt to reverse circulate. Annulus pressured up immediately to 1000 psi. Held steady. 04:30 - 06:00 1.50 PULL P DECOMP Work packer & screen assy up & down to wear out rubbers. .06:00 - 07:00 1.00 PULL P DECOMP Circulate bottoms up @ 3 bpm I 550psi, thru choke. Gas back wI bottoms up & cleaned up OK. 07:00 - 07:30 0.50 PULL P DECOMP Stand back kelly, blow down lines. Monitor well, well stable. 07:30 - 11 :30 4.00 PULL P DECOMP PJSM. POOH w/3 1/2" DP & fish. Pulling slowly to wear out rubbers, overpulled 20K wI 19 stands out, then pulled smoothly. 11 :30 - 12:30 1.00 PULL P DECOMP PJSM. UD Halliburton packer I screen assembly. 12:30 - 13:30 1.00 PULL P DECOMP Clear I clean rig floor. 13:30 - 17:00 3.50 CLEAN P DECOMP PJSM. M/U mule shoe & RIH on 31/2" DP, 88 stands. Single in & tag 6' in on # 276 @ 8717'. 120K up wt, 85K down wt. 17:00 - 19:30 2.50 CLEAN P DECOMP PJSM. M/U headpin. Circulate Jt # 276 down to 8741', pumping 5 bpm I 900 psi. Reverse out fill @ 5 bpm I 900 psi to clean returns. Wash & reverse circulate down to 8791' Tagged up hard wI 5-10K down. 19:30 - 20:30 1.00 CLEAN P DECOMP Reverse circulate hole clean. 5 BPM @ 900 psi. SID & monitor well Prep to POOH & LDDP. 20:30 - 21 :30 1.00 CLEAN P DECOMP RID head pin & circulating equip. POOH & LDDP. Pull & UD 15 jts. Check flow. Very slight flow. 21 :30 - 23:30 2.00 CLEAN P DECOMP Circulate bottoms up. Had some gas to surface. 5 BPM @ 1200 psi. SID & monitor well. Still have slight flow. Returns were 11.6 ppg. 23:30 - 00:00 0.50 CLEAN P DECOMP Mix NaBr & weight up to 11.8 ppg. 5/31/2005 00:00 - 01 :00 1.00 CLEAN P DECOMP Mix NaBr & weight up to 11.8 ppg. 01 :00 - 02:30 1.50 KILL P DECOMP Circulate & kill well wI 11.8 ppg. 4 BPM @ 800 psi. Pump 300 bbls. Had 11.8 ppg returns. SID monitor well. Well dead. Monitor well, well stable. RID circulating equip. 02:30 - 09:30 7.00 CLEAN P DECOMP POOH & UD 31/2" DP. 09:30 - 10:00 0.50 CLEAN P DECOMP Clear I clean rig floor. 10:00 - 11 :00 1.00 PRFADD P DECOMP PJSM. NID flow nipple, nipple up shooting flange. 11 :00 - 13:00 2.00 PRFADD P DECOMP PJSM wI Schlumberger regarding perf gun safety and overview of job. Rig up E-Line BOPE & lubricator. Rig up sheaves. 13:00 - 14:30 1.50 PRFADD P DECOMP Make up gun assembly, including gamma ray tool, CCL, (20') 3 3/8" 6 spf powerjet perf gun, rollers & bullnose, & test equipment, gamma not working properly, send for replacement. Printed: 6/6/2005 11 :22:07 AM "\ " ) BP AMOCO Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-05 MPF-05 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/27/2005 Rig Release: 6/1/2005 Rig Number: Spud Date: 4/29/1997 End: 6/1/2005 Date From.. To Hours Task Gode NPT Phase Description of Operations 5/31/2005 14:30 - 16:30 2.00 PRFADD P DECOMP Make up gun assembly & RIH. Tie in, subtract 7', position gun wI top shot @ 8503' - 8523'. Fill hole & fire gun, good indication of firing at surface. Monitor well, well on slight vacuum. 16:30 - 17:30 1.00 PRFADD P DECOMP POOH wI 1 st gun run, ASF. 17:30 - 19:00 1.50 PRFADD P DECOMP Made up 3-3/8" HSD Powerjet with 6 spf with Gamma Ray and CCL, RIH make tie in run from 8240' to 8620'. Set depth summary for correlation log info & tool sketch for tool measurements 12.1' CCL to top shot. Fill hole 8 bbls. Set and fire at 8447.9'. Perforated interful 8460'-8472'. Monitor well, on slight vacuum. 19:00 - 21 :30 2.50 PRFADD P DECOMP POOH w/2nd gun run and RID Schlumberger & Shooting flange, N/U Flow nipple 21 :30 - 00:00 2.50 P RUNPRD Make up ESP, Centralizer,190 HP KMH motor, Upper and Lower tandem seals, Gas seperator, Pump 151 GC1700, Discharge head, MS-1 pressure head. Make splice between discharge head & top handling pup. Check conductivity. 6/1/2005' ,00:00 - 06:00 6.00 RUNCOMP RUNCMP Run 2-7/8" ESP completion with 2.205 No-Go nipple, 1" KBMM GLM (open) at bottom and 1" KBMM GLM wldummy at top; Checking conductivity of cable every 2000' & pumping down tubing. 06:00 - 06:30 0.50 RUNCOMP RUNCMP Service rig. 06:30 - 08:00 1.50 RUNCOMP RUNCMP Continue in hole wi 27/8" ESP completion string, checking cable & pumping down tubing every 2000'. 08:00 - 1 0:30 2.50 RUNCOMP RUNCMP PJSM. W/81 stands in the hole @ 7900' (+ -), make reel to reel splice & test, OK. 10:30 - 11 :00 0.50 RUNCOMP RUNCMP Continue in hole w/2 7/8" ESP completion. 11 :00 - 13:00 2.00 RUNCOMP RUNCMP PJSM. P/U landing jt, M/U hanger & install penetrator. Install field connection & test, OK. Land hanger & RILDs. Install 2 way check valve & test to 3500 psi, OK. Ran total of (3) flat guards, (5) protectrolizers & (137) La Salle Clamps. 59K up wt, 44K down wt. 13:00 - 14:00 1.00 BOPSUP P RUNCMP PJSM. NID BOPE. 14:00 - 16:00 2.00 WHSUR P RUNCMP PJSM. N/U FMC 2 7/8" x 5M Gen V tree. Test tree & void to 5000 psi, 10 minutes, OK. 16:00 - 18:00 2.00 WHSUR P RUNCMP PJSM. Pull two way check valve, set BPV. Clean pits, secure well. Rig released @ 18:00 hrs, 06/01/2005. Printed: 6/6/2005 11 :22:07 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging_ Perforate_ ACIDIZED ESP & SCREENS Pull tubing _ Alter easing _ Repair well _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 41 feet 3. Address Exploratow__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Miline Point Unit 4. Location of well at surface 3545' FNL, 2783' FEL, Sec. 06, T13N, R10E, UM (asp's541782, 6035186) MPF-05 At top of productive interval 9. Permit number / approval number 4510' FNL, 867' FEL, Sec. 01, T13N, R09E, UM (asp's 538543, 6034203) 197-0740 At effective depth 10. APl number 4514' FNL, 866' FEL, Sec. 01, T13N, R09E, UM (asp's 538544, 6034199) 50-029-22762-00 At total depth 11. Field / Pool 4516' FNL, 866' FEL, Sec. 01, T13N, R09E, UM (asp's 538544, 6034197) Miline Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 8895 feet Plugs (measured) true vertical 7459 feet Effective depth: measured 8797 feet Junk (measured) true vertical 7361 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 78' 20" 250 sx AS I (Approx.) 112' 112' Surface 5538' 9-5/8" 1436 sx PF 'E', 600 sx 'G' 5570' 4576' Intermediate 8853' 7" 250 sx Class 'G' 8880' 7444' ~.., ~:~ .. -: Perforation depth: measured Open Perfs 8478' - 8498' true vertical Open Perfs 7042' - 7062' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 8246'. PHD w/6 fin Centralizer @ 8303'. /, ,, 3-1/2" Micron Poroplus Screen below Packer to 8481'. Packers & SSSV (type & measured depth) 7" x 2-7/8" HES Versatrieve Packer @ 8388' 2-7/8" x 1" sidepocket KBMM GLM Camco @ 137' & 8089' 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Avera.qe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __X Gas __ Suspended __ Service __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~~~[~~ Title: Technical Assistant Date January 18, 2002 Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE~ MPF-05 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 01/06/2OO2 01/06/02 SCALE INHIBITION: ACIDIZE ESP EVENT SUMMARY ESP WOULD NOT START AFTER A PAD SHUT DOWN. PUMPED NALCO EC6085 SCALE INHIBITION DOWN THE TUBING THROUGH THE ESP WITH IA FLUID PACKED WITH DEAD CRUDE. FOLLOWED BY 10 BBLS OF 10% HCL ACID TO ACIDIZE ESP AND SCREENS. LET SOAK FOR 15 MINUTES. STARTED ESP, RAN FOR 10 MINUTES. RVS, 10 MINUTES FWD, 10 MINUTES RVS. SHUT DOWN AND LET SIT SOAK FOR 8 HOURS. BROUGHT ON TO A TANK UNTIL A PH OF 6 AND RETURNED TO PRODUCTION. FLUIDS PUMPED BBLS DISCRIPTION 46 DIESEL 97 DEAD CRUDE 320 SOURCE WATER 10 10% HCL ACID 473 TOTAL Page 1 .... , STATE OF ALASKA .... ALASK/- ~,L AND GAS CONSERVATION COMN .... _~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change out ESP 2. Name of Operator 15. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 41.30' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 1735' NSL, 2783' WEL, SEC. 06, T13N, R10E, UM MPF-05 At top of productive interval 9. Permit Number / Approval No. 197-074 769' NSL, 868' WEL, SEC. 01, T13N, R09E, UM 10. APl Number At effective depth 50-029-22762-00 765' NSL, 866' WEL, SEC. 01, T13N, R09E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 763' NSL, 867' WEL, SEC. 01, T13N, R09E, UM Sands 12. Present well condition summary Total depth: measured 8895 feet Plugs (measured) true vertical 7459 feet Effective depth: measured 8797' feet Junk (measured) true vertical 7361 feet Casing Length Size Cemented M D TVD Structural Conductor 78' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 5538' 9-5/8" 1436 sx PF 'E', 600 sx 'G' 5570' 4576' Intermediate Production 8853' 7" 250 sx Class 'G' 8880' 7444' Liner Perforation depth: measured 8478' - 8498' RECEIVED true vertical 7042' - 7062' JUN 29 2001 Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 8305' Alaska 0il & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) 7" HES Versatrieve Packer at 8388'. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Si~lned Sondra~~ Title Technical Assistant Date Prepared By Name/Number: Sondra Stewman, 564-4750 Submit In Duplicate Form 10-404 Rev. 06/15/88 ~Co Page1 of 1 mmary Report Legal Well Name: MPF-05 Common Well Name: MPF-05 Spud Date: 4/29/1997 Event Name: REPAIR Start: 12/10~2000 End: 12/13/2000 Contractor Name: Ri9 Release: Rig Name: Rig Number: ~ From-To Hours Activity'i~odej~NP~l~?hase Description of Operations 1211012000 01:00 - 11:00 10.00 MOB P DEOOMP Move rig from MPC-14 & set in same & incident on windwall occurred as derrick was being raised. 11:00 - 14:00 3.00 MOB C DEOOMP repair windwalls around bottom of derrick & due inspection of same. Rig Accept @ 1400 Hrs. 12/10/2000 14:00 - 16:30 2.50 RIGU P PRE set tiger tank (Note: high winds and Iow windchills) 16:30 - 20:00 3.50 RIGU 3 PRE raise derrick and finish setting tiger tank. 20:00 - 21:00 1.00 WHSUR : DECOMP rig lubricator & pull bpv 21:00 - 22:30 1.50 RIGU : DEGOMP Nipple up lines to tree & test same to 3000 psi. 22:30 - 00:00 1.50 KILL ~ DEOOMP Tbg. Psi. =1800 psi. annulus psi. =2370 psi. & Open choke and begin circ. well with 11.7+ ppg. brine. 12/11/2000 00:00 - 02:00 2.00 KILL 3 DECOMP FINISH CIRC 11.7 BRINE AROUNG & SHUT IN WELL TBG. 70-PSI. ANNULUS-170 02:00 - 05:00 3.00 KILL ~ DECOMP RAISE WT. TO 11.9 PPG. & CIRC. AROUND USING CHOKE. 05:00 - 07:00 2.00 KILL P DECOMP MONITOR WELL BORE SLIGHT FLOW ON ANNULUS FLOWED BACK TOTAL OF 8-BBL. DECREASING TO PENCIL STREAM (NOTE:SEEMS AS WELL IS BALLOONED AS IT WAS TAKING FLUID AS WT. WAS BEING RAISED THROUGH CHOKE. TBG. DEAD. 07:00 - 07:30 0.50 WHSUR P DECOMP SET TWO & TEST SAME. TO 1000 PSI. 07:30 - 08:30 1.00 WHSUR P DECOMP NIPPLE DOWN TREE. 08:30 - 10:30 2.00 BOPSUF:P DECOMP NIPPLE UP BOP & ADAPTER 10:30 - 11:30 1.00 BOPSUF,P DECOMP TEST BOP TO 250-LOW & 3500 HIGH. (TEST WAIVED BY JEFF JONES WITH AOGC 11:30- 12:30 1.00 BOPSUFP DEOOMP PULL TWO. 12:30 - 18:00 5.50 KILL ~ DECOMP MAKE UP LANDING JOINT. TO HANGER & ANNULUS HAD A SLIGHT TRICKLE OF FLUID. CIRC. BOTTOMS UP AND OBSERVE WELL FLOW SLIGHT RAISE WT TO 12.1 PPG. & CIRC. AROUND AND MONITOR WELL TBG. DEAD & IANNULUS DEAD. AFTER MONITORING 1-HOUR. 18:00 - 18:30 0.50 PULL P DECOMP BOLDS & PULL HANGER TO FLOOR. 18:30 - 00:00 5.50 PULL P DECOMP PULL ESP COMPLETION TO 5500' 12/12/2000 00:00 - 04:00 4.00 PULL P DECOMP finish pulling esp completion & lay dn same. 04:00 - 07:00 3.001 RUNCO~ P COMP Make up esp completion & inspect same. 07:00 - 09:00 2.00 RUNCO~ P COMP change esp cable, spool around, correctly. 09:00 - 10:00 1.00 RUNCO~ COMP Make up protectalizers & fiat guards on esp assy. 10:00 - 15:30 5.50 RUNCOI~tP COMP rih with esp assy to 7400' 15:30 - 17:30 2.00 RUNCOI~ COMP change esp cable spools & splice esp cable. 17:30 - 20:30 3.00 RUNCOI~ COMP cont. to rih to setting depth @8402' & mu hanger & landing jr. & make splice at eft connector & land hanger & rilds. 20:30 - 21:00 0.50 RUNCOr~ COMP set twc & test to 1000 psi. 21:00 - 22:00 1.00 BOPSUF P COMP Nipple down bop 22:00 - 00:00 2.00 WHSUR P COMP Nipple up tree & test same to 5000 psi. & pull twc & set bpv. 12/13/2000 00:00 - 01:00 1.00 WHSUR P DECOMP secure tree area & cln-up. Rig Released @ 0100 Hrs. 12/13/2000 Printed: 6t20/2001 11:04:41 AM ,~ STATE OF ALASKA : ALASK/ AND GAS CONSERVATION COMf REPORT OF SUNDRY WELL OPERATIONS 31ON 1, Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other FCC For RWO 2. Name of Operator 5. Type of well: i6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 41.30' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 1735' NSL, 2783' WEL, SEC. 06, T13N, R10E, UM MPF-05 9. Permit Number/ Approval No. At top of productive interval 197-074 769' NSL, 868' WEL, SEC. 01, T13N, R09E, UM 10. APl Number At effective depth 50-029-22762-00 765' NSL, 866' WEL, SEC. 01, T13N, R09E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 763' NSL, 867' WEL, SEC. 01, T13N, R09E, UM Sands 12. Present well condition summary Total depth: measured 8895 feet Plugs (measured) true vertical 7459 feet Effective depth: measured 8797' feet Junk (measured) true vertical 7361 feet Casing Length Size Cemented M D TVD Structural Conductor 78' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 5538' 9-5/8" 1436 sx PF 'E', 600 sx 'G' 5570' 4576' Intermediate Production 8853' 7" 250 sx Class 'G' 8880' 7444' Liner Perforation depth:- measured 8478'- 8498' i"!~ !:~ ..;¢~' F true vertical 7042' - 7062' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 8406' ,'.l;..:-::~.l f)!!.. ~. "'¢'.'.;,.::. (:,:1::;. i~;0h'lr,']i*°'r,,, l.). Packers and SSSV (type and measured depth) None "' 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure "i'4.' ..... Represe'ni'~.i'ive Daily Avera,qe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Michael Williams ~~~¢J"' ~ Title Technical Assistant Date i: .... : :::: : . : :"- 7: ::: .: - ~ :: Prepared By Name/Number: Del/~/ay-ne~chnor'r564-5174 Form 10-404 Rev. 06/15/88 Submit In Duplicatex, 01/15/2001 MPF-05 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS DRILL-PREP WORK: FCO FOR RWO SUMMARY MIRU DS CTU #5. PU 1.75" JSN. RIH WHILE CIRCULATING DOWN COIL TO OPEN TOP TANK. TAG PUMP AT 8340' CTMD. CIRCULATE OUT, WASHING MANDREL AT 8188' THROUGHLY. CHASE OOH. FREEZE PROTECT TUBING WITH MEOH. BLOW DOWN REEL FOR PIPE SWAP. RD. Fluids Pumped BBLS. Description 148 2% KCL (DOUBLE SLICK) 7O 60/40 MEOH ,. 218 Total STATE OF ALASKA .... ALASKA ,_ AND GAS CONSERVATION COMb, REPORT OF SUNDRY WELL OPERATIONS ~ION 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change out ESP , 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 41.30' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 1735' NSL, 2783' WEL, SEC. 06, T13N, R10E, UM MPF-05 At top of productive interval 9. Permit Number / Approval No. 197-074 769' NSL, 868' WEL, SEC. 01, T13N, R09E, UM 10. APl Number At effective depth 50-029-22762-00 765' NSL, 866' WEL, SEC. 01, T13N, R09E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 763' NSL, 867' WEL, SEC. 01, T13N, R09E, UM Sands 12. Present well condition summary Total depth: measured 8895 feet Plugs (measured) true vertical 7459 feet Effective depth: measured 8797' feet Junk (measured) true vertical 7361 feet Casing Length Size Cemented MD TVD Structural Conductor 78' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 5538' 9-5/8" 1436 sx PF 'E', 600 sx 'G' 5570' 4576' Intermediate Production 8853' 7" 250 sx Class 'G' 8880' 7444' Liner Perforation depth: measured 8478' 8498' i-~ ~;:~ :i...: ~;;,~ ..... true vertical 7042' - 7062' J~ E B 0 7 ~ 0 01 ' . Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 8406' Alaska 0il & Gas Cons1 Anchora~qe Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Avera,qe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service 17. I hereby certify that the fo, r, egoing is ~ect to the best of my knowledge Signed TerrieHubble~'f,~f~/r/'n' ~ Title TechnicalAssistant Date Prepared By Name/Number: Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate :: OPerations sUmmary Report Legal Well Name: MPF-05 Common Well Name: MPF-05 Spud Date: 12/10/2000 Event Name: REPAIR Start: 12/10/2000 End: 12/13/2000 Contractor Name: NABORS Rig Release: 12/13/2000 Group: RIG Rig Name: NABORS 4ES Rig Number: 4 Date :Fr°m~IT° HourS I': Task cSc~dbe: PhaSe i Description of Operations 12/10/2000 01:00 - 11:00 10.00 MOB DECOMP Move rig from MPC-14 & set in same & incident on windwall occurred as derrick was being raised. 11:00 - 14:00 3.00 MOB DECOMP repair windwalls around bottom of derrick & due inspection of same. Rig Accept @ 1400 Hrs. 12/10/2000 14:00 - 16:30 2.50 RIGU PRE set tiger tank (Note: high winds and Iow windchills) 16:30 - 20:00 3.50 RIGU PRE raise derrick and finish setting tiger tank. 20:00 - 21:00 1.00 WHSUR DECOMP rig lubricator & pull bpv 21:00 - 22:30 1.50 RIGU DECOMP Nipple up lines to tree & test same to 3000 psi. 22:30 - 00:00 1.50 KILL DECOMP Tbg. Psi. =1800 psi. annulus psi. =2370 psi. & Open choke and begin circ. well with 11.7+ ppg. brine. 12/11/2000 00:00 - 02:00 2.00 KILL DECOMP FINISH ClRC 11,7 BRINE AROUNG & SHUT IN WELL TBG. 70-PSI. ;ANNULUS-170 02:00 - 05:00 3.00 KILL DECOMP RAISE WT. TO 11.9 PPG. & CIRC. AROUND USING CHOKE. 05:00 - 07:00 2.00 KILL DECOMP MONITOR WELL BORE SLIGHT FLOW ON ANNULUS FLOWED BACK TOTAL OF 8-BBL. DECREASING TO PENCIL STREAM (NOTE:SEEMS AS WELL IS BALLOONED AS IT WAS TAKING FLUID AS WT. WAS BEING RAISED THROUGH CHOKE, TBG. DEAD. 07:00 - 07:30 0.50 WHSUR DECOMP SET TWC & TEST SAME. TO 1000 PSI. 07:30 - 08:30 1.00 WHSUR DECOMP NIPPLE DOWN TREE. 08:30 - 10:30 2.00 BOPSUF DECOMP NIPPLE UP BOP & ADAPTER 10:30 - 11:30 1.00 BOPSUF DECOMP TEST BOP TO 250-LOW & 3500 HIGH. (TEST WAIVED BY JEFF JONES WITH AOGC 11:30- 12:30 1.00 BOPSUF DECOMP PULLTWC. 12:30 - 18:00 5.50 KILL DECOMP MAKE UP LANDING JOINT. TO HANGER & ANNULUS HAD A SLIGHT TRICKLE OF FLUID. CIRC. BOTTOMS UP AND OBSERVE WELL FLOW SLIGHT RAISE WT TO 12.1 PPG. & CIRC. AROUND AND MONITOR WELL TBG. DEAD & ANNULUS DEAD. AFTER MONITORING 1-HOUR. 18:00 - 18:30 0.50 PULL DECOMP BOLDS & PULL HANGER TO FLOOR. 18:30 - 00:00 5.50 PULL DECOMP PULL ESP COMPLETION TO 5500' 12/12/2000 00:00 - 04:00 4.00 PULL DECOMP finish pulling esp completion & lay dn same. 04:00 - 07:00 3.00 RUNCOIt COMP Make up esp completion & inspect same. 07:00 - 09:00 2.00 RUNCO~ COMP change esp cable, spool around, correctly. 09:00 - 10:00 1.00 RUNCOIt COMP Make up protecta zers & fiat guards on esp assy. 10:00 - 15:30 5.50 RUNCOk COMP i rih with esp assy to 7400' 15:30 - 17:30 2.00 RUNCOk COMP change esp cable spools & splice esp cable. 17:30 - 20:30 3.00 RUNCOr COMP cont. to rah to setting depth @8402' & mu hanger & landing jt. & make I splice at eft connector & land hanger & raids. 20:30 - 21:00 0.50 RUNCO~ COMP set twc & test to 1000 psi. 21:00 - 22:00 1.00 BOPSUF COMP Nipple down bop 122:00 - 00:00 2.00 WHSUR COMP Nipple up tree & test same to 5000 psi. & pull twc & set bpv. 12/13/2000 00:00 - 01:00 1,00 WHSUR DECOMP secure tree area & cln-up. Rig Released @ 0100 Hrs. 12/13/2000 F_F8 0 7 2001 Alaska Oil & (:-as Cons. Comrr~ission Anchorage Printed: 12/20/2000 7:41:53 PM : i o iera i nS summary Report Legal Well Name: MPF-05 Common Well Name: MPF-05 Spud Date: 12/10/2000 Event Name: REPAIR Start: 1/30/2001 End: Contractor Name: NABORS Rig Release: 2/4/2001 Group: RIG Rig Name: NABORS 4ES Rig Number: 4 :: iD~te: :~ro~ ~ ~~:t rsI phase :i:t ~ i Description of Operations 1/30/2001 06:00 - 10:00 4.00 MOB PRE MOVE FROM F-81 TO F-05. & RAISE DERRICK & SAFE OUT OPERATION (RIG ACCEPT @ 1000 HRS. 01/30/01) 10:00- 11:00 1.00 KILL DECOMP RIG LUBRICATOR & PULL BPV. 11:00 - 14:30 3.50 KILL DECOMP RIG LINES FROM TREE TO THRASH TANK & PRESSURE TEST SAME TO 3000 PSI. 14:30 - 20:00 5.50 KILL DECOMP TAKE ON 12.1 PPG. BRINE & HEAT TO 100 DEG/& WT. OF BRINE FELL TO 11.9 PPG. DUE TO TEMP. INCREASE & LET FLUID COOL & WT. INCREASED TO 12.1 PPG. 20:00-23:00 3.00 KILL DECOMP CIRC. WELL THROUGH CHOKE TO KILLWITH 12.1 PPG. 23:00 - 00:00 1.00 KILL DECOMP SHUT DOWN & MONITOR WELL TBG=130 PSI. ANNULUS = 150 PSI. 1/31/2001 00:00 - 03:00 3.00 KILL DECOMP WT. FLUID TO 12.2 PPG. & CIRC, WELL BORE WITH SAME. 03:00- 09:30 6.50 KILL DECOMP WT. FLUID TO 12.4 AND ATTEMPT TO RAISE YP OF FLUID TO 15 WITH N-VIS AND PUMP SAME. & MONITOR WELL SLIGHT FLOW. AFTER 1-HR. MONITORING. 09:30 - 12:00 2.50 KILL DECOMP RAISE WT. TO 12.5 PPG. & PUMP SAME & MONITOR WELL SLIGHT FLOW TO ANNULUS SIDE FOR 1-HOUR. 12:00 - 14:00 2.00 KILL DECOMP RAISE WT. TO 12.6 PPG. & PUMP SAME. & MONITOR WELL BORE (WELL STATIC BOTH SIDES) 14:00 - 15:00 1.00 WHSUR DECOMP RIG LUBRICATOR & SET TWC & TEST. 15:00- 16:00 1.00 WHSUR DECOMP NIPPLE DOWN TREE. 16:00- 18:00 2.00 BOPSUF~ COMP NIPPLE UP BOP'S 18:00 - 21:00 3.00 BOPSUF~ COMP PRESSURE TEST BOP'S TO 250 --LOW & 3500 HIGH. (TEST / WAIVED BY CHUCK SHEVE WITH AOGC. 21:00 - 22:00 1.00 BOPSUF~ COMP RIG LUBRICATOR & PULL TWC. 22:00 - 22:30 0.50 PULL COMP MAKE UP LANDING JT. & BOLDS & PULL HANGER TO FLOOR & TEST ESP CABLE & LAY DN HANGER. 22:30 - 00:00 1.50: PULL i COMP POOH WITH ESP COMPLETION. i 2/1/2001 00:00 - 08:00 8.00 PULL COMP POOH & LAY DN ESP EQUIPMENT. (NOTE:BOTTOM 4-JOINTS TBG. PLUGGED. WITH DEBRI. 08:00 - 10:30 2.50 PULL COMP CLEAN RIG FLOOR & SET WEAR RING. 10:30 - 14:00 3.50 CLEAN COMP MAKE UP 6" MILL & RIH ON 3.5" DP. TO 4500' 14:00 - 16:00 2.00 CLEAN COMP MU KELLY & CIRC. SWEEP & ROTATE & RECIPROCATE NOTE: : NOTHING SEEN OF SIGNIFICANT VALUE IN RETURNS AT i SURFACE. ;16:00-17:30 1.50 CLEAN ~ COMP CONTINUE TO RIH WITH 3.5" DP TO 6500' 17:30 - 19:00 1.50 CLEAN COMP MU KELLY & CIRC SWEEP & RECIPROCATE & ROTATE (6-BPM & 120 RPM. NOTHING OF SIGNIFICANTS SEEN IN RETURNS 19:00 - 20:30 1.50 CLEAN COMP CONTINUE TO RIH WITH 3.5" DP TO 8478' (TAG FILL) 20:30 - 00:00 3.50 CLEAN COMP WASH FILL F/8478' TO 8634' RETURNS FRAC SAND & RUBBER & SHALE. 2/4/2001 00:00 - 01:30 1.50 RUNCOI~ COMP circ 12.6 brine from well bore with sea H20 01:30 - 02:00 0.50 RUNCOI~I COMP run & set bpv 02:00 - 03:00 1.00 RUNCOIV~ COMP clean & secure tree area. rig released @ 0300 hrs 02/04/2001 Anchoraqe. - · Printed: 2/6/2001 2:26:13 PM 01',I OR BEFORE .... ~ STATE OF ALASKA ALASK. JIL AND GAS CONSERVATION COM...3SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 41.30' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 1735' NSL, 2783' WEL, SEC. 06, T13N, R10E, UM MPF-05 At top of productive interval 9. Permit Number / Approval No. 197-074 769' NSL, 868' WEL, SEC. 01, T13N, R09E, UM 10. APl Number At effective depth 50-029-22762-00 765' NSL, 866' WEL, SEC. 01, T13N, R09E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 763' NSL, 867' WEL, SEC. 01, T13N, R09E, UM Sands 12. Present well condition summary Total depth: measured 8895 feet Plugs (measured) true vertical 7459 feet Effective depth: measured 8797' feet Junk (measured) true vertical 7361 feet Casing Length Size Cemented M D TVD Structural Conductor 78' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 5538' 9-5/8" 1436 sx PF 'E', 600 sx 'G' 5570' 4576' Intermediate Production 8853' 7" 250 sx Class 'G' 8880' 744d' Liner ORIGINAL Perforation depth: measured 8478'-8498' RECEIVED true vertical 7042'-7062' APR 1 8 2000 Tubing (size, grade, and measured depth) 2-7/8" 6.5# L-80 at 8387' A~a~ka 0il & Gas C~qs. C0mmissi0r~ Packers and SSSV (type and measured depth) None Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge ~,,,- - Signed TerrieHubb,e fl,¢~[/~ ~ Title Technical Assistantlll Date :ii i :: ~i: ::i::: ::i :., PfeparedBy Name/Number: Terrie Hubble Form 10-404 Rev. 06/15/88 Submit In Duplicate,,,,.l Progress Report Facility M Pt F Pad Well MPF-05 Page 1 Rig Nabors 4ES Date 11 April 00 Date/Time 06 Apr 00 18:00-00:00 18:00-00:00 07Apr 00 00:00 00:00-05:00 00:00-05:00 05:00 05:00-06:00 05:00-06:00 06:00 06:00-13:30 06:00-13:30 13:30 13:30-15:00 13:30-15:00 15:00 15:00-16:30 15:00-16:30 16:30 16:30-18:00 16:30-18:00 08 Apr 00 18:00 18:00-19:30 18:00-19:00 19:00 19:00-19:30 19:30 19:30-23:30 19:30-23:30 23:30 23:30-06:00 23:30-06:00 06:00 06:00-08:30 06:00-08:30 08:30 08:30-22:30 08:30-11:00 11:00 11:00-14:30 14:30 14:30-17:00 17:00 17:00-19:00 Duration 6 hr 6hr 5hr 5hr lhr lhr 7-1/2 hr 7-1/2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr lhr 1~ hr 4hr 4hr 6-1/2 hr 6-1/2 hr 2-1/2 hr 2-1/2 hr 14hr 2-1/2 hr 3-1/2 hr 2-1/2 hr 2hr Activity Move rig Rig moved 100.00 % move rig from F-50 & rig up & and safe out equipment. At well location - Slot Fluid system Fill pits with Brine rig hard lines & take on fluid & test lines to 3500 psi. & pull bpv. & hold well kill PJSM Completed operations Well control Circulated closed in well at 8287.0 ft Kill well with 11.0 PPG. Brine. Stopped: To hold safety meeting crew change Well control (cont...) Circulated closed in well at 8287.0 ft circ. well & raise brine wt. to 11.5 ppg. Hole displaced with Brine - 250.00 % displaced Wellhead work Removed Xmas tree Equipment work completed Nipple up BOP stack Installed BOP stack Equipment work completed Test well control equipment Tested BOP stack This was a ammended to the AOGC rules test. & waived by John Crisp. Pressure test completed successfully - 3500.000 psi Wellhead work Removed Hanger plug Equipment work completed Removed Tubing hanger Equipment work completed Fluid system Circulated at 8287.0 ft circ. & raise wt. to 11.7 ppg.1 Hole displaced with Brine - 125.00 % displaced Pull Single completion, 2-7/8in O.D. Pulled Tubing in stands to 250.0 ft Stopped: To hold safety meeting Pull Single completion, 2-7/8in O.D. (cont...) Rigged down sub-surface equipment - ESP Equipment work completed Run Single completion, 2-7/8in O.D. Rigged up sub-surface equipment - ESP Equipment work completed Ran Tubing in stands to 5300.0 ft Stopped: To splice cable Serviced ESP make mid-line splice Equipment work completed Ran Tubing in stands to 8153.0 ft RECEIVE '8 000 Ata~ka Oil & Gas Con,,. Commissior:, Anchorage Facility M Pt F Pad Progress Report Well MPF-05 Page 2 Rig Nabors 4ES Date 11 April 00 Date/Time 09 Apr 00 19:00 19:00-22:30 22:30 22:30-23:00 22:30-23:00 23:00 23:00-00:00 23:00-00:00 00:00 00:00-06:00 00:00-01:30 01:30 01:30-03:00 03:00 Duration 3-1/2 hr 1/2 hr 1/2 hr 1 hr lhr 6 hr 1-1/2 hr 1-1/2 hr Activity On bottom Installed Tubing hanger MU tbg. hanger & make ESP cable connector & mu to same & land hanger. Equipment work completed, seal energised Wellhead work Installed Hanger plug Equipment work completed Wellhead work Removed BOP stack Equipment work completed Wellhead work Installed Xmas tree test tree to 5000 psi. Equipment work completed Installed Hanger plug pull twc & install bpv. Equipment work completed REC:tVED APR 18 2000 Ala,ka Oii& Gas Co~s, ¢onmssior Anohoi'~e PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 07/19/99 RUN RECVD ..... 97-074 TEMP/PRES SRVY 97-074 GR/CCL 97-074 PERF 97-074 7732 97-074 DGR/EWR4-TVD 97-074 DGR/EWR4-MD 97-074 DGR/CNP-MD 97-074 DGR/CNP-TVD 97-074 7749 97-074 MWD SRVY 97-074 MMS SRVY 97-074 MMS SRVY 97-074 GYRO MULTI SHOT 8200-8540 j.~'82oo-854o ~-'~SPERRY ~12-7463 ~14-8895 ~' 114-8895 ~112-7463 ~CHL~ ~PERRY ~SPERRY SPERRY ~RODATA GR/CCL/PDC 0-8896 0-8754 0-5460 0-8750 FIAi~L 07/03/97 FI~NL 07/03/97 FIANL 07/03/97 1,2 07/23/97 FINAL 07/30/97 FINAL 07/30/97 FINAL 07/30/97 FINAL 07/30/97 1 07/11/97 09/12/97 09/12/97 09/12/97 09/12/97 10-407 ~C~MPLETION DATE @ 7/ ~/~ 7/ DAILY WELL O~S ~ ~/IP~lg71 TO )~/~Xl q~ Are dry ditch samples required? yes ~_.~And received? Was the well cored? yes ~Analysis & description received? Are well tests required?l/~es n~>-Received? --~ruD_ Well is in compliance Initial COMMENTS @ q~//~, ~. ?/ T D BOX .... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG REVISED: 09/10/97 1. Status of Well Classification of Service Well [~ Oil [] Gas [~ Suspended [--i Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-74 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22762 4. Location of well at surface ?~ ........... ;%~;~;?~'~'r~':~,*"'~:-'--~ i ~ ~ 9. Unit or Lease Name 1735' NSL, 2783' WEL, SEC. 6, T13N, R10E, UM ; ......... Milne Point Unit Atto, of produ ct ive interval ! -~-'~--~-~--7 I~t 10. Well Number 770' NSL, 869' WEL, SEC. 1 T13N, RDE, UM " MPF-05 At total depth i -----~-~-~,!~ ) 11. Field and Pool 764' NSL, 868' WEL, SEC. 1, T13N, RDE, UM ........... ~ .... ,. Milne Point Unit / Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands KBE = 44'I ADL 388235 12. Date Spudded 113. Date T.D. Reached i 14. Date Comp., Susp., or Aband.115. Water depth, if offshore 16. No. of Completions 4/29/97 5/5/97 5/24/97 N/A MSL One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+'I-VD)I19. Directional Survey 120. Depth where SSSV set J21. Thickness of Permafrost 8895 7459 FTI 8797' 7361 FTI []Yes [] NoI N/A MD I 1800' (Approx.) 22. Type Electric or Other Logs Run Gyro, MWD, GR/CDR, EMSS, RLL, GR/JB 23. CASING~ LINER AND CEMENTING RECORD CASING SE-FrING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 34' 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 32' 5570' 12-1/4" 1436 sx PF 'E', 600 sx 'G' 7" 26# L-80 27' 8880' 8-1/2" 250 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3 3/8" Gun Diameter, 6 spf 2 7/8", 6.5, L-80 8375' N/A MD TVD MD TVD 8478'-8498' 7042'-7062' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 85 bbls diesel Frac 8478'-8498' 144945# 16/20 Carbolite behind pipe 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 6/18/97I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED iOIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presenc,~ o;Loik~clas or water. Submit core chips. ~laska Oil & Gas Oo~s, Core,miss, Anchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. TKUP 8289' 6853' TKA3 8455' 7019' TKA2 8471' 7035' TKS1 8501' 7065' 31. List of Attachments Summary of Daily Drilling Reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ChipAIvord ~~ *~' (~ Title Senior Drilling Engineer Date MPF-05' 97-74 Prepared By Name/Number: Kathy Campoamor, 564-5122 Well Number Permit No, / Approval No. INSTRUCTIONS GENERAL.' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Facility M Pt F Pad Progress Report Well MPF-05 Page 1 Rig Nabors 22E Date 27 August 97 Date/Time 28 Apr 97 16:01-18:00 18:00-03:00 29 Apr 97 03:00-06:00 06:00-08:30 08:30-12:00 12:00-17:00 17:00-17:30 17:30-18:00 18:00-18:15 18:15-06:00 30 Apr 97 06:00-12:00 12:00-13:00 13:00-14:00 14:00-15:00 15:00-15:30 15:30 01 May 97 06:00-07:00 07:00-08:30 08:30-10:00 10:00-11:00 11:00-12:30 12:30-00:00 02 May 97 00:00-02:00 02:00-03:30 03:30-05:00 05:00-06:00 06:00-07:00 07:00-07:30 07:30-11:00 11:00-14:30 14:30-15:15 15:15-15:30 15:30-23:30 23:30-00:00 03 May 97 00:00-01:00 01:00-01:15 01:15-02:00 02:00-02:30 02:30-04:00 04:(g}-05:00 05:00-05:30 05:30-06:00 ' ~' 06:00-07:30 07:30-09:30 09:30-10:30 10:30-13:30 13:30-17:00 17:00-17:30 17:30-20:00 20:00-21:00 21:00-22:00 22:00-22:30 22:30-02:30 04 May 97 02:30-04:00 Duration 1-3/4 hr 9hr 3hr 2-1/2 hr 3-1/2 hr 5hr 1/2 hr 1/2hr 1/4hr 11-3/4 hr 6hr lhr lhr lhr 1/2 hr lhr 1-1/2 hr 1-1/2 hr lhr 1-1/2 hr 11-1/2 hr 2hr 1-1/2 hr 1-1/2 hr lhr lhr 1/2 hr 3-1/2 hr 3-1/2 hr 3/4 hr 1/4hr 8hr I/2hr lhr 1/4hr 3/4 hr 1/2hr 1-1/2 hr lhr 1/2 hr 1/2 hr 1-1/2 hr 2hr lhr 3hr 3-1/2 hr 1/2 hr 2-1/2 hr lhr lhr 1/2 hr 4hr 1-1/2 hr Activity Rigged down Drillfloor / Derrick Rig moved 100.00 % Rigged up Drillfloor / Derrick Rig moved 100.00 % Rigged up Divertor Made up BHA no. 1 Functioned Divertor Circulated at 112.00 ft Held safety meeting Drilled to 1491.00 ft Drilled to 2333.00 ft (cont...) Circulated at 2333.00 ft Pulled out of hole to 207.00 ft Serviced Top drive R.I.H. to 2333.00 ft Drilled to 4397.00 ft Drilled to 4493.00 ft (cont...) ~:"~ Circulated at 4493.00 ft Pulled out of hole to 1118.00 ft Serviced Top drive R.I.H. to 4493.00 ft Drilled to 5585.00 ft Circulated at 5585.00 ft Pulled out of hole to 1118.00 ft R.I.H. to 5585.00 ft Circulated at 5585.00 ft Circulated at 5585.00 ft (cont...) Dropped EMSS survey barrel Pulled out of hole to 1118.00 ft Pulled BHA Rigged up Casing handling equipment Held safety meeting Ran Casing to 5570.00 ft (9-5/8in OD) Rigged up Cement head Circulated at 5570.00 ft Pumped Fresh water spacers - volume 75.000 bbl Mixed and pumped slurry - 258.000 bbl Displaced slurry - 416.000 bbl Circulated at 2005.00 ft Mixed and pumped slurry - 414.000 bbl Displaced slurry - 152.000 bbl Cleared Bell nipple Rigged down Casing handling equipment Rigged down Diverto£ Installed Casing spool Rigged up BOP stack Tested BOP stack Installed Wear bushing Made up BHA no. 2 Singled in drill pipe to 2005.00 ft Drilled installed equipment - DV collar Field drill (H2S) Singled in drill pipe to 5423.00 ft Tested Tubular strings - Via annulus and string Facility M Pt F Pad Progress Report Well MPF-05 Page 2 Rig Nabors 22E Date 27 August 97 Date/Time 04:00-05:00 05:00-06:00 06:00-07:00 07:00-08:00 08:00-08:30 08:30-16:00 16:00-17:00 17:00-18:00 18:00-19:00 19:00-06:00 05 May 97 06:00-12:00 12:00-13:00 13:00-14:30 14:30-15:30 15:30-16:30 16:30-23:30 23:30-01:00 06 May 97 01:00-02:30 02:30-04:00 04:00-05:30 05:30-06:00 06:00-06:30 06:30-11:00 11:00-13:30 13:30-14:30 14:30-16:00 16:00-16:15 16:15-22:00 22:00-22:30 22:30-02:30 07 May 97 02:30-03:00 03:00-06:00 06:00-09:30 09:30-09:45 09:45-10:00 10:00-11:00 11:00-11:30 11:30-12:30 12:30-13:30 13:30-16:00 16:00-22:00 22:00-00:00 08 May 97 00:00-01:00 Duration lhr lhr lhr lhr 1/2 hr 7-1/2 hr lhr lhr lhr llhr 6hr lhr 1-1/2 hr lhr lhr 7hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 1/2hr 4-1/2 hr 2-1/2 hr lhr 1-1/2 hr l/4hr 5-3/4 hr 1/2 hr 4hr 1/2 hr 3hr 3-1/2 hr 1/4 hr 1/4 hr lhr lhr lhr 2-1/2 hr 6hr 2hr lhr Activity Serviced Block line Serviced Top drive Drilled installed equipment - Float collar Circulated at 5605.00 ft Performed formation integrity test Drilled to 6431.00 ft Circulated at 6431.00 ft Drilled to 6526.00 ft Circulated at 6526.00 ft Drilled to 7652.00 ft Drilled to 8217.00 ft (cont...) .. Circulated at 8217.00 ft Pulled out of hole to 5550.00 ft Serviced Top drive R.I.H. to 8217.00 ft Drilled to 8895.00 ft ~- Circulated at 8895.00 ft .;~::-~- Pulled out of hole to 5570.00 ~t R.I.H. to 8895.00 ft Circulated at 8895.00 ft Dropped EMSS survey barrel Dropped EMSS survey barrel (cont...) Pulled out of hole to 1095.00 ft Pulled BHA Worked on BOP - Top ram Rigged up Casing handling equipment Held safety meeting Ran Casing to 5400.00 ft (7in OD) Circulated at 5400.00 ft Ran Casing to 8880.00 ft (7in OD) Rigged up Cement head Circulated at 8880.00 ft Circulated at 8880.00 ft (cont...) Pumped Synthetic based mud spacers - volume 70.000 bbl Mixed and pumped slurry - 51.000 bbl Displaced slurry - 336.000 bbl Tested Casing Rigged down Cement head Installed Seal assembly Rigged down BOP stack Installed Tubing head spool Freeze protect well - 70.000 bbl of Diesel Serviced Block line Performance Enquiry Report Operator BP Exploration Date 01:05, 28 Aug 97 Page 1 The analysis is from - 08:30, 04 May 97 - to - 08:30, 04 May 97 Programs in Result Table: MPF-05 DRILL AND COMPLETE Well Type Time From Time To Duration DescriDtion E.M.W.(equivalent mud weight) MPF-05 Event 08:30, 04 May 97 08:30, 04 May 97 0 hr 0 min Obtained leak off 12.800 Hole Size MDR 8-1/2 Milne Point Unit, Ak. TO: S. Rossberg FROM: J. Fox Well Name: IMP F-05 Main Category:IWireline Sub Category: Initial perforations Operation Date: 05/18/97 MPU F LE COpy Date: Io5 8 97 I Purpose: In preparation for the initial completion of this well a primary correlation log, gyro survey, perforation of the Kup 'A' Sand, and the SBHP survey need to be performed. Sequence of Events: 0830 - E-Line equipment arrived on location. Standby for adjacent rig operations (load out tubing). 1000 - MIRU. 1120 - RIH w/GR/CCL toolstring on magnetically marked line. Correct depths to magnetic marks. Tag bottom at 8789' RKB. Log up to 5341' RKB (surface casing). POOH. 1400 - MU and RIH w/Gyrodata gyro toolstring. Perform gyro survey, from surface to just above PBTD and back to surface. 2000 - Hold tailgate safety meeting. Establish radio silence. Make up 20' x 3 3/8" hollow carrier, gun perforating toolstring. Pressure test lubricator to 1500 psig - ok. RIH and depth correct to short joints on GR/CCL primary correlation Icg from first run. RIH, depth correct to lithology. Log up to 8474.5. CCL to top shot = 3.5'. Pwh = 250 psig. Detonate gun perforating 7" production casing from 8478' to 8498' RKB. Pwh = 500 psig. Log off and POOH. All shots fired. 2315 - RIH with pressure / temperature toolstring. Depth correct to shod joints. FIIH position pressure gauge at 8488' RKB (midperf). Monitor pressures for 63 minutes. Pressures falling slightly initially then stabilized. POOH. RDMO. Results: A GR/CCL correlation Icg was run from PBTD (measured at 8789' RKB) to surface. Depths were based on magnetic line marks zeroed at original drilling rig floor. This will establish the primary depth correlation for this well. Depths were 4' deeper relative to the open hole MWD Icg depths at the Kuparuk interval. Perforation depths were modified accordingly. ~'i) ~ ~ Me'U FILE COPY A gyro survey was run throughout the entire wellbore. Result are being processed by Gyrodata. The 7" production casing was perforated from 8478' to 8498' RKB w/3 3/8", 6 JSPF, 22.5 gm RDX charges (0.56" EHD, 12.89" TTP). Performed a SBHP. Pressures were falling off initially (from line displacement) and then stabilized. Initial pressure was 2976 psia. Pressures dropped 1.3 psi in the last 30 minutes and 0.14 psi in the last 10 minutes. Final temperature and pressure were 172.0 deg. F and 2957.4 psia. At a TVD of 7052' the EMW - 8.06 ppg. Diesel Used [2 bbl. J Methanol Used [none J SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPF-05 Rig Name: N-4ES AFE: 347071 Accept Date: 05/21/97 Spud Date: - Release Date: 05/24/97 May 22, 1997 MIRU & raise derrick, berm rig & safe out equipment. Rig accepted 05/21/97 @ 1500 hrs. Take on source water & spot TT. ND frac tree, NU BOP's. Test BOP's. Test waived by John Spaulding w/AOGCC. Install wear ring & load pipe shed with 2-7/8" tubing & prep. MU Baker retrieving tool & RIH. Displace freeze protection. Cont to RIH with Baker retrieving tool. May 23, 1997 Test casing, ok. Engage & release plug & monitor well. RIH to 8400'. CBU & clean fluid & monitor well. POOH. Change rams to 4-1/2" & test BOP's. PU & RIH with 4-1/2" workstring with taper to 3-1/2". Rig Dowell & test lines. Perform injectivity test & data frac & send to town for design. Perform frac as design, 144945# 16/20 behind & left 5700# in casing. RD Dowell & monitor well for carrier to break. May 24, 1997 Monitor gel break on frac proppant carrier final. PU DP & RIH. Tag sand @ 8454' Clean frac sand out of 7", 8454'-8792'. Rev circ until well bore clean of frac sand. POOH to 8438'. Mix & pump casing wash & follow with filtered seawater. POOH, LD workstring. Pull wear ring & set test plug & change rams to 2-7/8" & test same. PU & MU ESP assy. May 25, 1997 Service ESP. RIH with ESP assy & make splice at hanger. Land tubing. Set TWC & ND BOP & NU tree & test, ok. Rig lines to tree & test & freeze protect well with diesel & set BPV. Secure tree & cellar. Rig released 05/24/97 @ 2000 hrs. Page ]. MPU FILE COPY BP EXPLORATION (ALASKA)INC. Milne Point Unit TO: S. Rossberg FROM: J. Fox DATE: 05/23/97 RE: F-05 DATA FRAC AND FRAC SERVICE CO'S.: B J, Peak, Nabors JOB SUMMARY INJECTIVITY TEST Design Rate, Bbls Max Rate, Final lAP psi ISIP, NWB friction, Treat grad, BPM Pumped bpm PSI psi psi/ft Max. 187 38 2763 not appl. n/a 0.84 DATA FRAC Bbls Bbls XLgel Time XL gel on Final IA STP, ISIP f/lAP, NWB friction, Treat grad, Pumped to Perfs perfs psi psi psi psi/ft 165 150.7 4.75 min. 2733 2535 30 0.81 FRAC Sand Lead prop Tail prop Design total Treesaver pumped, behind pipe, behind behind pipe, Liner Sand, rubber left in Job was M# lbs./size pipe, M# M# M# hole? /size Flush 150,645 144,945 not appl. 102,000 5700 not appl. 16/20 Ft of sand Estimated Final ISIP, psi ISIP Incr Actual TSO, design, TSO, in Pipe sand top SLAP, over datafrac sand:pad min Nolte psi ratio Plot 260' 8200' 3480 not not avail. 8.4 not avail. 8.2 recorded Operational problems 06/03/97 9:53 AM DATA FRAC & FRAC SENT VIA MICROSOFT MAIL TIME I RATE ANNP WHP STAGE I BPM PSIGI PSIG BBL PUI~, ~IG SUMMARY CUMBBL I COMMENTS · Due to pad congestion the frac fleet had to set up on the opposite side of the pad header system creating longer than usual treating lines and rig up. · During the Injectivity step the rate was designed to have been slowed down to 30 bpm 100 bbls. before the pad was on perfs. Instead it was slowed down 37 bbls. after pad hit peals. Error due to bad information provided by BPX on-site Eng. · Right at the end of the data frac the blender road engine seized up. The radiator from this engine was removed and hooked up to the deck engine. There was approx. 2.5 hours of down time for these repairs. When ready to pump the frac it was discovered that the 2" return line and treating line pressure transducer were froze up. Thawed out the pressure transducer and replaced the return line. · Data link with Anchorage dropped out during data frac. Data could not be viewed real time and had to be E-Mailed at the end of the data frac. Comments Originally this well was slated for a casing frac as it had favorable azimuth and hole angle. Due to · logistics and rig scheduling the workover rig was put over the well earlier than expected creating the need for a rig frac. However, having the ability to monitor annulus pressure and the reduced flush volume was beneficial in optimizing the frac. Monitoring extrapolated measured bottomhole pressures (rather than calculated), knowing that there was a good chance of getting all of the flush away, and knowing the consequences of a pre-mature screen out were relative small made calling flush easier to manage. We ended up pumping 42% excess as opposed to 10 to 20 % that may have been pumped on a casing frac. MPU FILE COPY DATE/TIME I OPERATIONS SUMMARY 05/22/97 DATA FRAC 0800 MIRU frac, vac, pump. AMBIENT=19 deg. F, WC - 8 deg. F, WIND=9 MPH. SIWHP-- 0, lAP- 0 2145 Hold pre-job safety meeting. 2217 Start Injectivity test / data frac. 2227 Shut down pumps and monitor data frac falloff pressures. 05/23/97 0245 Prepare to frac. Discovered 2" return line is froze up. 0327 Start pumping frae as per revised design. 0358 Shut down pumps. Monitor pressure fall off. 0413 Start rig down. PUMPING SUMMARY TIME RATE ANNP WHP STAGE CUM COMMENTS BPM PSlG PSlG BBL BBL 05/22/97 BREAKDOWN / DATA FRAC DISPLACEMENT = 137 BBLS 2216 0 81 40 0 0 Prepare to start Injectivity Test. 2217 13 53 255 0.6 Start pumping seawater at max rate to break down perfs. 2219 29 2539 4696 50 Swap to crosslinked 40 ppt. guar gel. 2222.5 36.6 2730 4320 187 Gel on perfs 2223 36.2 2755 4403 215 Swap to seawater for flush 2224 30.1 2737 4137 250 Reduce rate to 30 BPM. 2227 29.9 2733 3185 337 With 150 bbl. of X.L. gel into the formation shut down pump. Monitor pressure falloff. IA ISIP - 2535 psig. 2228 0 2457 2489 2230 0 2351 2357 2235 0 2136 2137 2240 0 1900 1903 2245 0 1706 1716 2250 0 1422 1436 2255 0 1182 1198 2300 0 992 1002 2304 0 877 887 I MPU FILE COPy PUMPING SUMMARY TIMEI RATE ANNP WHP STAGEI CUM COMMENTS BPM PSIG PSIG BBL BBL 0327 0 - 166 178 337.7 Prepare to start frac job. 0328 6.0 1516 1913 338 Start pumping 40 ppt. crosslinked guar hel pad. 0328.5 30 2510 3391 351 Rate Established. 0331 29.8 2448 3414 419 Stage 1 ppg 16/20 Carbolite slurry. 0333 29.8 2497 3734 475 Pad on perfs. 0335 30.2 2656 3780 561 3.5 ppg slurry 0337 29.9 2675 3684 607 4.5 ppg slurry 0339 30.1 2653 3602 670 6.2 ppg slurry 0341 30.1 2647 3583 723 7.7 ppg slurry 0343 30.1 2653 3583 781 9.3 ppg slurry 0345 29.9 2671 3620 842 Start of 10.0 ppg slurry 0347 29.9 2704 3734 904 10 ppg 0349 30.1 2754 3821 960 10 ppg. 0352 30.1 2895 4032 1039 10 ppg - at design sand volume. 0354.5 29.8 3116 4293 1127 10 ppg - Call flush. Flush with 15 bbl. XL gel then seawater. 0356 29.75 3211 4554 1168 on flush 0358 29.2 3479 4458 1230 With 15 bbls. of underdisplacement shut down pumps. Monitor falloff pressures. 0400 0 3202 3181 0402 0 3019 2993 0404 0 2898 2865 0410 0 2578 2544 0413 I 0 2459 2425 MPU FILE COPY !997 Page 5 FLUIDS PUMPED DOWNHOLE INJ TEST& DATA FRAC: 338 Bbls FRAC: 896 Bbls 1234 TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME INONE PETREDAT WIN DOW GEL QUALITY CONTROL CHECK SEA H20 SEA H20 40# GEL 40/t GEL PIPE XL XL pH TEMP pH VISCOSITY TIME TIME pH DF/FRAC 7.5 84 deg. F 7.24 3.3 4:36 2:16 8.74 FLUID ADDITIVES Guar: (J877) 9.7 gpt Surfactant: (F-75) 1.0 gpt Bactericide: (M275) 0.3 gpt Antifoam: Activator: (J899) 5.0 gpt Boric Acid: (Y6) 2.2 gpt S.P. Breaker (J218) 1.5 ppt MPU FILE COPY B.P. EXPLORATION F PAD, WELL NO. MPF-05 MILNE POINT FIELD, ALASKA Gyro Multishot Survey Inside 7"CASING Survey date: 17 - MAY, 1997 Job number :A0597GCE401 ORIGINAL STATE OF ALASKA ALASI4:.~ _)IL AND GAS CONSERVATION CO:.MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [--J Operation Shutdown []Stimulate [] Plugging I~ Perforate [] Pull Tubing []Alter Casing I--] Repair Well [] Other Change out ESP 2. Name of Operator 15. Type of well: 6. [] Development BP Exploration (Alaska)Inc. I [] Exploratory 7. 3. Address [] Stratigraphic P.O. Box 196612, Anchorage, Alaska 99519-6612 i--I Service 4. Location of well at surface 8. 1735' NSL, 2783' WEL, SEC. 6, T13N, R10E, UM 9. At top of productive interval 770' NSL, 869' WEL, SEC. 1, T13N, R9E, UM At effective depth 766' NSL, 868' WEL, SEC. 1, T13N, R9E, UM At total depth 764' NSL, 868' WEL, SEC. 1, T13N, R9F, UM Datum Elevation (DF or KB) KBE = 44' Unit or Property Name Milne Point Unit Well Number MPF-05 Permit Number / Approval No. 97-74 10. APl Number 50-029-22762 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 8895 feet true vertical 7459 feet Effective depth: measured 8797' feet true vertical 7361 feet Casing Plugs (measured) Junk (measured) Length Size Cemented Structural Conductor 78' 20" 250 sx Arcticset I (Approx.) Surface 5538' 9-5/8" 1436 sx PF 'E', 600 sx 'G' Intermediate Production 8853' 7" 250 sx Class 'G' Liner MD TVD 112' 112' 5570' 4576' 8880' 7444' Perforation depth: measured 8478'-8498' true vertical 7042'-7062' Tubing (size, grade, and measured depth) 2-7/8" 6.5# L-80 at 8357' Packers and SSSV (type and measured depth) N/A 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL 14. Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Chip AIvord /. _~~. ~. ('"-~ Title Senior Drilling Engineer Prepared By Name/Number: I16. Status of well classifications as: [~ Oil I--I Gas [] Suspended Service Date .)(/ f ( f ) ? Kathy Campoamor, 564-5122 Form 10-404 Rev. 06/15/88 Submit In Duplicate SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPF-05 Rig Name: N-4ES ArE: 347071 Accept Date: 07/06/97 Spud Date: - Release Date: 07/08/97 July 7, 1997 RU lines to tiger tank. Rig accepted 07/06/97 @ 0600 hrs. Test lines, good test. Displace well with filtered seawater. Monitor. Install TVVC. ND tree. NU BOP's. Test BOPE. AOGCC waived the right to witness test, B. Foster. MU landing jt. Fill hole. Monitor well. Pull hanger. LD hanger & landing jt. Start POOH with ESP assy & 2-7/8" tubing. Finish POOH with ESP assy & tubing. LD ESP assy. RU Halliburton WL and RIH with GR/JB. Set down at 8530'. POOH. RD. MU mule shoe. RIH with 2-7/8" tubing to top of fill at 8550'. Rev circ. Wash out down to 8684', start 10 bbl sweep. Carbolite in returns. July 8, 1997 Rev circ & CO circ to PBTD. Rev circ gel sweeps. Clean/condition wellbore. Clean rig pits. Wait on clean seawater. Rev casing & displace with filtered seawater. Rev 2 hole volumes. Monitor well. Start POOH with tubing. Finish POOH. LD mule shoe. MU & service ESP assy. Re-run motor per Anch PE/Centrilift. New seal section shaft did not turn freely. Had to re-set shims. Ok now. Start RIH with ESP assy & 2-7/8" tubing. MU tubing hanger & landing jt. July 9, 1997 Splice upper pigtail cable. Check cable, ok. Land hanger, RILDS. LD landing jr. Install TVVC. ND BOP's. NU tree. Check ESP cable, ok. Test tubing hanger & tree, good. Pull TWC. Install BPV. Freeze protect well with diesel to 2100' TVD. Blow down lines. Well secure. Rig released 07/08/97 @ 1400 hrs. Page 1 CONTENTS JOB NUMBER :A0597GCE401 1. DISCUSSION , SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT 1. DISCUSSION , SURVEY CERTIFICATION SHEET DISCUSSION JOB NUMBER' A0597GCE401 Tool 768 was run in WELL# MPF-05 on SCHLUMBERGER 3/8" wireline inside 7"CASING. The survey was run without problems. SURVEY CERTIFICATION SHEET JOB NUMBER' A0597GCE401 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- ROB SHOUP OPERATIONS MANAGER 2. SURVEY DETAILS SURVEY DETAILS JOB NUMBER: A0597GCE401 CLIENT: B.P. EXPLORATION RIG: SCHLUMBERGER LOCATION: F PAD, ALASKA WELL: MPF-05 LATITUDE: 70.505 N LONGITUDE: 149.5 W SURVEY DATE: SURVEY TYPE : 17, MAY, 1997 GYRO MULTISHOT IN 7" CASING DEPTH REFERENCE: 41.3' MAX. SURVEY DEPTH: ROTARY TABLE ELEVATION 8750' SURVEY TIED ONTO: NA SURVEY INTERVAL: 0-8750' APl NUMBER: 050-029-227 TARGET DIRECTION: 254.60 GRID CORRECTION: N/A CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: TOM STODDARD 3. OUTRUN SURVEY LISTING A Gyro da t a Di r e c t i ona i Survey for B.P. EXPLORATION F PAD, WELL NO. MPF-05 MILNE POINT FIELD, ALASKA Job Number: A0597GCE401 Run Date: 17-May-97 15:30:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction from Vertical Reference: 41.3 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 254.600 deg Vertical Section Calculated from Well Mead Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference B.P. EXPLORATION F PAD, WELL NO. MPF-05 MILNE POINT FIELD, ALASKA Job Number: A0597GCE401 A Gy r o d a t MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet 0.0 0.00 0.00 0.0 100.0 .10 315.01 100.0 201.0 .12 201.10 201.0 299.0 .05 41.86 299.0 402.0 .11 132.96 402.0 500.0 .06 237.17 500.0 600.0 .10 111.02 600.0 700.0 .16 26.40 700.0 799.0 .10 90.04 799.0 901.0 .27 125.28 901.0 999.0 .30 119.73 999.0 1100.0 .37 110.63 1100.0 1199.0 .44 128.04 1199.0 1300.0 .46 122.83 1300.0 1399.0 .54 118.25 1399.0 1500.0 .65 133.89 1500.0 1600.0 .67 128.24 1600.0 1700.0 .61 127.12 1700.0 1800.0 .73 141.44 1800.0 1900.0 .65 146.13 1900.0 2001.0 1.63 218.20 2000.9 2100.0 4.14 242.70 2099.8 2199.0 6.28 248.49 2198.4 2298.0 9.37 254.36 2296.5 2400.0 12.38 255.93 2396.6 a Di r e c t i ona I Survey DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. 0.0 0.00 0.0 0.0 .0 .10 .1 315.0 .2 .18 .2 280.7 .2 .17 .2 260.3 .1 .12 .1 226.4 .1 .1 -.8 -1.3 -1.8 -2.3 -2.9 -3.5 -4.1 -4.8 -5.4 -5.8 -4.8 8.7 22.1 41.3 .15 .2 194.6 .14 .2 182.2 .18 .2 133.9 .15 .3 90.9 .19 .6 104.2 .04 1.1 112.4 .09 1.7 113.2 .14 2.3 115.3 .04 3.1 117.8 .10 4.0 118.4 .20 5.0 120.1 .07 6.1 122.1 .06 7.3 123.0 .21 8.4 124.6 .10 9.5 127.0 1.55 10.2 136.2 2.77 10.5 163.5 2.22 14.7 200.8 3.22 25.4 225.2 2.97 43.1 238.1 Page HORIZONTAL COORDINATES feet 0.00 N 0.00 E .06 N .06 W .03 N .17 W .03 S .17 W .06 S .07 W .16 S .04 W .22 S .01 W .13 S .13 E .00 S .28 E .14 S .57 E .41 S .98 E .65 S 1.52 E 1.00 S 2.11 E 1.45 S 2.76 E 1.89 S 3.50 E 2.51 S 4.33 E 3.27 S 5.20 E 3.95 S 6.09 E 4.77 S 6.91 E 5.74 S 7.62 E 7.35 S 7.05 E 10.10 S 3.00 E 13.72 S 5.21 W 17.88 S 18.01 W 22.77 S 36.61 W A Gyrodata B.P. EXPLORATION F PAD, WELL NO. MPF-05 MILNE POINT FIELD, ALASKA Job Number: A0597GCE401 MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet 2500.0 15.07 257.77 2493.8 2550.0 16.62 257.49 2541.9 2600.0 17.42 257.53 2589.7 2650.0 18.99 258.44 2637.2 2700.0 19.83 258.75 2684.3 2750.0 20.44 258.89 2731.3 2800.0 21.32 258.71 2778.0 2850.0 22.39 258.21 2824.4 2900.0 23.73 257.09 2870.4 2950.0 24.97 255.81 2915.9 3000 . 0 26 . 57 253 . 93 2961 . 0 3050.0 27.82 253.40 3005.4 3100.0 29.18 253.72 3049.4 3150 . 0 30 . 23 253 . 83 3092 . 8 3200 . 0 31 . 56 254 . 03 3135 . 7 3250.0 32.72 254.21 3178.1 3300.0 33.98 254.22 3219.8 3350.0 35.01 254.20 3261.0 3400.0 36.09 254.04 3301.7 3450.0 37.03 253.53 3341.9 3500.0 38.13 253.09 3381.5 3550.0 39.31 252.73 3420.5 3600.0 40.62 252.71 3458.8 3650.0 41.65 252.80 3496.5 3700.0 42.49 253.03 3533.6 65.0 78.7 93.3 108.9 125.5 142.6 160.4 179.0 198.5 219.1 240.9 263.7 287.6 312.3 338.0 364.6 392.1 420.4 449.5 479.2 Directional DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. 2.72 66.0 244.8 3.10 79.4 247.0 1.60 93.8 248.6 3.20 109.2 249.9 1.69 125.7 251.1 1.22 142.8 252.0 1.76 160.5 252.8 2.19 179.0 253.4 2.82 198.5 253.8 2.69 219.1 254.0 3 . 60 240 . 9 254 . 1 2 . 53 263 . 7 254 . 1 2 . 73 287 . 6 254 . 0 2 . 11 312 . 3 254 . 0 2 . 67 338 . 0 254 . 0 2.32 364.6 2.52 392.1 2.07 420.4 2.17 449.5 1.98 479.3 509.7 2.26 509.8 541.0 2.41 541.0 573.1 2.61 573.1 606.0 2.07 606.0 639.4 1.71 639.5 254.0 254.0 254.0 254.0 254.0 254.0 253.9 253.8 253.8 253.7 Survey Page HORIZONTAL COORDINATES feet 28.13 S 59.72 W 31.06 S 73.05 W 34.22 S 87.33 W 37.47 S 102.61 W 40.76 S 118.90 W 44.09 S 135.79 W 47.55 S 153.27 W 51.28 S 171.50 W 55.47 S 190.64 W 60.31 S 210.68 W 65.99 S 231.66 W 72.42 S 253.58 W 79.17 S 276.46 W 86.09 S 300.25 W 93.19 S 324.92 W 100.47 S 350.50 W 107.95 S 376.95 W 115.65 S 404.20 W ~' 123.61 S 432.16 W 131.93 S 460.75 W 140.69 S 489.96 149.88 S 519 86 Wi~[ 159.42 S 550 52 169.17 S 581.93 179 01 S 613 96 W~ A Gyroda t a D i r e c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-05 MILNE POINT FIELD, ALASKA Job Number: A0597GCE401 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL C 0 0 R D I N A T E S feet 3750 . 0 43 . 30 253 . 27 3570 . 2 3800 . 0 44 . 00 253 . 39 3606 . 4 3850 . 0 45 . 20 253 . 52 3642 . 0 3900 . 0 46.06 253 . 54 3677 . 0 3950 . 0 47 . 32 253 . 60 3711 . 3 673.5 1.65 673.5 253.7 188.87 S 646.53 W 708.0 1.41 708.1 253.7 198.77 S 679.59 W 743.1 2.40 743.2 253.7 208.77 S 713.24 W 778.8 1.73 778.9 253.7 218.90 S 747.51 W 815.2 2.52 815.3 253.7 229.19 S 782.41 W 4000.0 48.06 253.77 3744.9 4050.0 49.03 254.09 3778.0 4100.0 49.66 254.86 3810.6 4150.0 50.37 255.30 3842.7 4200.0 51.07 255.57 3874.4 852.2 1.50 852.3 253.7 239.58 S 817.90 W 889.6 1.99 889.7 253.7 249.95 S 853.91 W 927.6 1.72 927.7 253.7 260.11 S 890.45 W 965.9 1.58 966.0 253.8 269.97 S 927.47 W 1004.6 1.47 1004.6 253.8 279.70 S 964.93 W 4250.0 52.12 255.73 3905.5 4300.0 53.31 255.79 3935.7 4350.0 54.69 255.76 3965.1 4400.0 56.10 255.73 3993.5 4450.0 57.58 255.64 4020.9 4500.0 59.31 255.23 4047.0 4550.0 60.46 255.03 4072.1 4600.0 60.52 254.82 4096.8 4650.0 60.46 253.68 4121.4 4700.0 60.34 252.97 4146.1 1043.7 2.11 1043.8 253.9 1083.5 2.38 1083.6 254.0 1123.9 2.77 1124.0 254.0 1165.1 2.82 1165.1 254.1 1206.9 2.96 1207.0 254.2 1249.5 3.52 1249.6 254.2 1292.8 2.33 1292.8 254.2 1336.3 .38 1336.3 254.2 1379.8 1.99 1379.8 254.2 1423.3 1.25 1423.3 254.2 289.41 S 1002.89 W 299.19 S 1041.44 W 309.13 S 1080.65 W 319.27 S 1120.54 W 329.62 S 1161.10 W 340.34 S 1202.33 W 351.44 S 1244.13 W 362.75 S 1286.15 W 374.57 S 1328.02 W 387.04 S 1369.67 W 4750.0 59.89 253.08 4171.0 4800.0 59.78 252.92 4196.1 4850.0 60.37 251.35 4221.1 4900.0 60.63 250.39 4245.7 4950.0 60.41 250.18 4270.3 1466.6 .92 1466.6 254.2 1509.8 .36 1509.9 254.2 1553.1 2.97 1553.2 254.1 1596.5 1.75 1596.6 254.0 1639.9 .56 1640.1 253.9 399.70 S 1411.13 W 412.34 S 1452.47 W 425.63 S 1493.71 W 439.90 S 1534.83 W 454.58 S 1575.80 W A Gyrodat B.P. EXPLORATION F PAD, WELL NO. MPF-05 MILNE POINT FIELD, ALASKA Job Number: A0597GCE401 MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet 5000.0 60.19 250.16 4295.1 5050.0 60.07 250.10 4320.0 5074.0 60.07 250.01 4331.9 5200.0 61.11 250.57 4393.8 5250.0 61.13 250.38 4418.0 5300.0 60.84 250.20 4442.2 5350.0 60.64 250.17 4466.7 5400.0 60.48 250.07 4491.2 5450.0 60.28 249.76 4515.9 5500.0 59.91 249.58 4540.9 5550.0 59.64 249.32 4566.0 5600.0 59.58 248.57 4591.3 5650.0 59.13 248.38 4616.8 5700.0 56.80 249.12 4643.3 5750.0 56.14 249.73 4671.0 5800.0 54.46 251.18 4699.4 5850.0 53.93 251.61 4728.7 5900.0 52.56 252.49 4758.6 5950.0 51.83 252.88 4789.3 6000.0 50.74 253.96 4820.5 6050.0 49.51 254.40 4852.6 6100.0 48.21 255.13 4885.5 6150.0 46.66 255.39 4919.3 6200.0 45.48 255.36 4954.0 6250.0 44.33 256.25 4989.4 1683.2 1726.5 1747.2 1856.7 1900.3 1943.9 1987.4 2030.8 2074.1 2117.3 2160.4 2203.3 2246.0 2288.2 2329.7 2370.7 2411.2 2451.2 2490.7 2529.7 2568.1 2605.7 2642.5 2678.5 2713.8 a Di rec t iona i Survey DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. .45 1683.4 253.8 .25 1726.7 253.7 · 31 1747 . 4 253 . 7 . 90 1857 . 0 253 . 5 .33 1900.7 253.4 .65 1944.4 253.3 .42 1988.0 253.3 .36 2031.4 253.2 .66 2074.8 253.1 .81 2118.1 253.1 .70 2161.2 253.0 1.29 2204.2 252.9 .95 2247.1 252.8 4.83 2289.4 252.7 1.66 2331.0 252.7 4.12 2372.1 252.7 1.28 2412.6 252.6 3.08 2452.7 252.6 1.59 2492.2 252.6 2.75 2531.2 252.6 2.55 2569.5 252.7 2.83 2607.2 252.7 3.12 2644.0 252.7 2.35 2679.9 252.8 2.62 2715.2 252.8 HORIZONTAL COORDINATES feet 469.32 S 1616.66 W 484.06 S 1657.44 W 491.15 S 1676.99 W 528.17 S 1780.32 W 542.80 S 1821.58 W 557.55 S 1862.74 W 572.34 S 1903.78 W 587.15 S 1944.73 W 602.07 S 1985.55 W 617.13 S 2026.19 W 632.29 S 2066.65 W 647.79 S 2106.89 W 663.57 S 2146.91 W 678.93 S 2186.41 W 693.58 S 2225.43 W 707.34 S 2264.17 W 720.27 S 2302.60 W 732.62 S 2340.71 W 744.38 S 2378.42 W 755.51 S 2415.81 W 765.97 S 2452.72 W 775.87 S 2489.05 W 785.24 S 2524.66 W 794.33 S 2559.50 W 802.99 S 2593.72 W Page A Gyro da t a D i r e c t i ona i B.P. EXPLORATION F PAD, WELL NO. MPF-05 MILNE POINT FIELD, ALASKA Job Number: A0597GCE401 MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. 6300.0 43.40 256.72 5025.5 6350.0 41.74 257.13 5062.3 6400.0 40.74 257.40 5099.9 6450.0 39.00 257.88 5138.2 6500.0 38.42 257.96 5177.3 2748.5 1.98 2749.8 252.8 2782.3 3.36 2783.5 252.9 2815.2 2.03 2816.4 252.9 2847.2 3.53 2848.3 253.0 2878.4 1.16 2879.5 253.1 6550.0 36.65 257.32 5216.9 6600.0 36.09 257.25 5257.2 6650.0 34.17 256.89 5298.1 6700.0 33.86 256.64 5339.5 6750.0 31.85 256.05 5381.5 2908.8 3.63 2909.8 253.1 2938.4 1.12 2939.4 253.1 2967.2 3.87 2968.1 253.2 2995 . 1 . 68 2996 . 0 253 . 2 3022.3 4.06 3023.1 253.2 6800.0 31.53 255.70 5424.0 6850.0 29.36 255.05 5467.1 6900.0 28.78 255.81 5510.8 6950.0 26.64 254.82 5555.1 7000.0 25.88 255.24 5600.0 3048.5 .76 3049.3 253.3 3073.8 4.37 3074.7 253.3 3098.1 1.37 3098.9 253.3 3121.4 4.39 3122.2 253.3 3143.5 1.57 3144.3 253.3 7050.0 24.29 254.84 5645.2 7100.0 23.35 255.84 5691.0 7150.0 22.53 256.05 5737.0 7200.0 20.99 255.90 5783.5 7250.0 20.03 254.64 5830.3 3164.7 3.19 3165.5 253.3 3184.9 2.06 3185.6 253.3 3204.4 1.63 3205.1 253.4 3222.9 3.09 3223.6 253.4 3240.4 2.12 3241.1 253.4 7300.0 18.37 254.97 5877.5 7350.0 17.74 254.94 5925.0 7400.0 15.85 255.11 5972.9 7500.0 13.33 253.02 6069.7 7600.0 11.37 250.82 6167.4 3256.9 3.32 3257.6 253.4 3272.4 1.26 3273.1 253.4 3286.8 3.79 3287.5 253.4 3312.0 2.57 3312.7 253.4 3333.4 2.02 3334.1 253.4 Survey Page HORIZONTAL COORDINATES feet 811.09 S 2627.41 W 818.74 S 2660.35 W 826.01 S 2692.50 W 832.87 S 2723.81 W 839.41 S 2754.39 W 845.93 S 2784.15 W 852.45 S 2813.07 W 858.89 S 2841.11 W 865.30 S 2868.34 W 871.70 S 2894.70 W 878.10 S 2920.17 W 884.50 S 2944.68 W 890.61 S 2968.20 W 896.50 S 2990.69 W 902.21 S 3012.06 W 907.68 S 3032.54 W 912.79 S 3052.07 W 917.53 S 3070.98 W 922.02 S 3088.96 W 926.47 S 3105.91 W 930.78 S 3121.77 W 934.80 S 3136.74 W 938.54 S 3150.70 W 945.41 S 3174.92 W 952.02 S 3195.26 W A Gyr oda t a D i r e c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-05 MILNE POINT FIELD, ALASKA Job Number: A0597GCE401 Page MEASURED DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 77 77 79 79 8O 00 98 00 99 99 .0 .0 .0 .0 .0 9.34 251.67 6265.7 7.22 257.12 6362.7 5.03 259.91 6464.1 2.71 263.26 6562.9 1.02 295.42 6662.8 3351.3 2.04 3352.0 253.4 3365.4 2.30 3366.1 253.4 3376.3 2.17 3377.0 253.4 3382.9 2.35 3383.6 253.4 3385.9 1.93 3386.6 253.4 957.81 S 3212.28 W 961.69 S 3225.84 W 963.90 S 3236.49 W 964.94 S 3243.09 W 964.83 S 3246.25 W 82 82 84 85 86 00 99 00 0O 01 .0 .0 .0 .0 .0 .14 39.97 6763.8 .41 135.79 6862.8 .53 98.66 6963.8 .48 129.57 7063.8 .82 158.64 7164.8 3386.5 1.05 3387.2 253.5 3386.2 .45 3386.9 253.5 3385.6 .32 3386.3 253.4 3385.0 .27 3385.7 253.4 3384.6 .46 3385.4 253.4 964.35 S 3246.98 W 964.52 S 3246.66 W 964.85 S 3245.94 W 965.18 S 3245.17 W 966.12 S 3244.58 W 8700 8750 Final 0 .95 172.47 7263 .8 0 1 . 03 183 · 41 7313 . 8 Station Closure: Distance: 3384.7 .25 3385.4 253.4 3384.9 .41 3385.7 253.4 3385.65 ft Az: 253.38 deg. 967.59 S 3244.22 w 968.45 S 3244.19 w A Gyroda t a D i r e c t i ona i Survey for B.P. EXPLORATION F PAD, WELL NO. MPF-05 MILNE POINT FIELD, ALASKA Job Number: SUB401 Run Date: 17-May-97 15:30:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction from Vertical Reference: 41.3 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 254.600 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyroda t a D i re c t iona i B.P. EXPLORATION F PAD, WELL NO. MPF-05 ~ILNE POINT FIELD, ALASKA 3ob Number: SUB401 SUBSEA DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. -41.3 100.0 200.0 300.0 400.0 0.'00 0.00 0.0 .11 268.43 141.3 .09 135.62 241.3 .08 79.28 341.3 .09 174.75 441.3 0.0 0.00 0.0 0.0 .1 .14 .2 301.0 .2 .18 .2 272.3 .1 .15 .1 246.3 .1 .13 .2 213.6 500.0 600.0 700.0 800.0 900.0 .08 185.07 541.3 .12 76.07 641.3 .13 52.95 741.3 .17 104.65 841.3 .28 123.00 941.3 .1 .14 .2 189.5 .0 .16 .2 162.3 -.2 .16 .3 115.9 -.4 .17 .6 96.4 -.6 .13 1.1 107.6 1000.0 1100.0 1200.0 1300.0 1400.0 .33 115.92 1041.3 .40 117.90 1141.3 .45 125.86 1241.3 .49 120.92 1341.3 .59 124.80 1441.3 -1.0 .06 1.7 112.8 -1.5 .11 2.3 114.1 -2.0 .10 3.1 116.3 -2.5 .07 4.0 118.0 -3.1 .14 5.0 119.1 1500.0 1600.0 1700.0 1800.0 1900.0 .66 131.56 1541.3 .64 127.78 1641.3 .66 133.04 1741.3 .70 143.38 1841.3 1.05 175.64 1941.3 Survey 2000.0 2100.0 2200.0 2300.0 2400.0 2.66 228.20 2041.3 5.04 245.13 2141.3 7.63 251.06 2241.3 10.71 255.06 2341.3 13.62 256.78 2441.3 HORIZONTAL COORDINATES feet 0.00 N 0.00 E .05 N .11 W .03 S .17 W .04 S .13 W .10 S .06 W .18 S .03 W .18 S .06 E .08 S .19 E .06 S .40 E .25 S .74 E .51 S 1.21 E .80 S 1.77 E 1.19 S 2.38 E 1.63 S 3.07 E 2.15 S 3.85 E -3.8 .14 6.1 121.0 2.83 S 4.69 E -4.4 .06 7.3 122.5 3.55 S 5.57 E -5.1 .12 8.4 123.7 4.29 S 6.43 E -5.6 .16 9.5 125.6 5.17 S 7.20 E -5.4 .69 10.2 130.8 6.40 S 7.39 E -3.0 2.04 10.5 147.3 3.5 2.54 14.7 179.2 14.6 2.66 25.4 211.5 30.7 3.11 43.1 231.0 52.2 2.86 66.0 241.2 8.47 S 5.40 E 11.62 S 3.93 W 15.54 S 10.81 W 20.07 S 26.34 W 25.24 S 47.24 W Page A Gyrodata ~.P. EXPLORATION PAD, WELL NO. MPF-05 4ILNE POINT FIELD, ALASKA Iob Number: SUB401 SUBSEA DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SECTION feet 2500.0 2600.0 2700.0 2800.0 2900.0 3000.0 3100.0 3200.0 3300.0 3400.0 3500.0 3600.0 3700.0 3800.0 3900.0 4000.0 4100.0 4200.0 4300.0 4400.0 16.60 257.49 2541.3 19.07 258.46 2641.3 20.63 258.86 2741.3 22.89 257.80 2841.3 25.87 254.75 2941.3 28.93 253.66 3041.3 31.71 254.06 3141.3 34.51 254.21 3241.3 37.02 253.54 3341.3 40.02 252.72 3441.3 42.66 253.08 3541.3 45.17 253.52 3641.3 47.98 253.75 3741.3 50.34 255.28 3841.3 53.57 255.78 3941.3 58.93 255.32 4041.3 60.36 253.11 4141.3 60.58 250.56 4241.3 60.23 250.10 4341.3 60.85 250.20 4441.3 4500.0 59.90 249.58 4541.3 4600.0 56.98 249.07 4641.3 4700.0 53.35 251.98 4741.3 4800.0 49.94 254.25 4841.3 4900.0 45.91 255.37 4941.3 78.5 110.3 146.4 186.2 231.4 283.2 341.5 406.8 478.8 558.4 646.6 742.4 848.2 964.1 1091.1 1240.2 1414.8 1588.8 1763.8 1942.3 2118.1 2284.9 2428.1 2554.6 2665.4 Directional DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. 3.10 79.4 246.9 3.07 125.7 250.0 1.33 160.5 252.2 2.42 198.5 253.5 3.20 240.9 254.1 2.70 287.6 254.0 2.62 364.6 254.0 2.28 420.4 254.0 1.98 479.3 254.0 2.52 573.1 253.9 1.69 673.5 253.7 2.38 743.2 253.7 1.61 852.3 253.7 1.58 966.0 253.8 2.45 1124.0 254.0 3.40 1249.6 254.2 1.40 1423.3 254.2 1.97 1596.6 254.0 .40 1857.0 253.6 .64 1944.4 253.3 .81 2161.2 253.1 4.53 2289.4 252.8 2.04 2452.7 252.6 2.62 2569.5 252.6 2.63 2679.9 252.7 Survey Page HORIZONTAL COORDINATES feet 31.02 S 72.89 W 37.76 S 104.04 W 44.84 S 139.55 W 52.82 S 178.54 W 63.51 S 222.49 W 77.93 S 272.26 W 94.15 S 328.30 W 111.96 S 391.15 W 131.81 S 460.35 W 155.06 S 536.50 W 181.08 S 620.80 W 208.57 S 712.57 W 238.46 S 814.07 W 269.52 S 925.81 W 301.07 S 1048.85 W 337.98 S 1193.28 W 384.62 S 1361.59 W 437.35 S 1527.49 W 496.75 S 1692.62 W 556.99 S 1861.19 W 617.39 S 2026.88 W 677.75 S 2183.36 W 725.48 S 2318.67 W 762.29 S 2439.73 W 791.00 S 2546.75 W A Gyr oda t a Di re c t i ona i Survey 3.P. EXPLORATION ? PAD, WELL NO. MPF-05 4ILNE POINT FIELD, ALASKA Iob Number: SUB401 Page SUBSEA DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 5000 · 0 42.68 256 · 89 5041.3 5100 . 0 38 · 96 257 · 89 5141 · 3 5200 · 0 36 . 31 257 · 28 5241 . 3 5300 · 0 33 · 78 256 · 61 5341 · 3 5400.0 30.66 255.44 5441.3 2763.0 2.57 2783.5 252.9 2849.6 3.35 2879.5 253.0 2926.8 2.11 2939.4 253.1 2996.3 .82 3023.1 253.2 3058.6 2.20 3074.7 253.3 814 · 38 S 833.38 S 849.88 S 865.57 S 880.66 S 2641.58 W 2726.20 W 2801.67 W 2869.47 W 2929.98 W 5500.0 27.31 255.13 5541.3 5600.0 24.43 254.87 5641.3 5700.0 22.39 256.04 5741.3 5800.0 19.64 254.72 5841.3 5900.0 17.10 255.00 5941.3 3114.1 3.45 3122.2 253.3 3162.9 3.05 3165.5 253.3 3206.1 1.77 3223.6 253.4 3244.3 2.40 3257.6 253.4 3277.3 2.12 3287.5 253.4 894.66 S 907.20 S 917.94 S 927.47 S 936.07 S 2983.67 W 3030.76 W 3072.64 W 3109.61 W 3141.48 W 6000.0 14.07 253.63 6041.3 6100.0 11.89 251.41 6141.3 6200.0 9.85 251.46 6241.3 6300.0 7.69 255.92 6341.3 6400.0 5.52 259.28 6441.3 6500.0 3.22 262.52 6541.3 6600.0 1.38 288.49 6641.3 6700.0 .33 96.91 6741.3 6800.0 .35 114.97 6841.3 6900.0 .50 106.93 6941.3 3304.6 2.93 3312.7 253.4 3327.7 2.16 3334.1 253.4 3346.8 2.03 3352.0 253.4 3362.3 2.24 3366.1 253.4 3373.8 2.20 3377.0 253.4 3381.4 2.31 3383.6 253.4 3385.3 2.02 3386.6 253.4 3386.4 1.25 3387.2 253.5 3386.3 .58 3386.9 253.5 3385.8 .35 3386.3 253.4 943.40 S 950.26 S 956.37 S 960.83 S 963.40 S 964.71 S 964.85 S 964.46 S 964.48 S 964.78 S 3167.82 W 3189.84 W 3208.06 W 3222.85 W 3234.10 W 3241.65 W 3245.57 W 3246.82 W 3246.73 W 3246.10 W 7000.0 .49 122.61 7041.3 7100.0 .74 151.88 7141.3 7200.0 .92 169.32 7241.3 7272.5 1.03 183.41 7313.8 3385.1 .28 3385.7 253.4 3384.7 .41 3385.4 253.4 3384.7 .30 3385.4 253.4 3384.9 .41 3385.7 253.4 965.11 S 965.90 S 967.26 S 968.45 S 3245.34 W 3244.72 W 3244.30 W 3244.19 W Final Station Closure: Distance: 3385.65 ft Az: 253.38 deg. 4. QUALITY CONTROL QUALITY CONTROL REPORT JOB NUMBER; A0597GCE401 TOOL NUMBER: 768 MAXIMUM GYRO TEMPERATURE: 79.8 C MAXIMUM AMBIENT TEMPERATURE: 78.7 C MAXIMUM INCLINATION: 61.13 AVERAGE AZIMUTH: 253.83 WIRELINE REZERO VALUE: N/A REZERO ERROR / K: N/A CALIBRATION USED FOR FIELD SURVEY: CALIBRATION USED FOR FINAL SURVEY :' 1995 1995 PRE JOB MASS BALANCE OFFSET CHECK: -.33 POST JOB MASS BALANCE OFFSET CHECK]: USED O.O/N/A CONTINUOUS CONDITION OF SHOCK WATCHES UPON ARRIVAL AT RIG: 1 OFF -.20 UPON COMPLETION OF SURVEY: UPON RETURN TO ATLAS I OFF I OFF BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH MWD 8807 1.16 190.37 FINAL SURVEY 8750 1.03 183.41 TVD 7374.8 7313.8 NORTHING - 915.25 -986.45 EASTING -3253.18 -3244.19 FUNCTION TEST JOB NUMBER' A0597GCE401 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 2500 15,04 15,04 15,04 15.04 15.04 AZIMUTH M.D. ft 1 2 3 4 5 2500 257.72 257.66 257.44 257.77 257.73 5. EQUIPMENT AND CHRONOLOGICAl. REPORT EQUIPMENT REPORT JOB NUMBER: A0597GCE401 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 768 GYRO SECTION DATA SECTION POWER SECTION BACKUP TOOL No. 773 GYRO SECTION DATA SECTION POWER SECTION A0159 C0100 C0040 A0163 C0089 C0086 COMPUTER A0349 POWER SUPPLY PRINTER A0079 INTERFACE A0143 COMPUTER A0222 POWER SUPPLY PRINTER A0029 INTERFACE A0055 A0085 A0107 WIRELINE COMPANY: CABLE SIZE: 3/8" SCHLUMBERGER RUNNING GEAR 2.5" HOUSING W/ECCENTRIC BAR AND ROLLERS TOTAL LENGTH OF TOOL :25' MAXIMUM O.D.: 4" INCHES TOTAL WEIGHT OF TOOL: 250 POUNDS CHRONOLOGICAL REPORT JOB NUMBER: A0597GCE401 SATURDAY,05/17/97 10:30 11:30 13:00 15:15 15:30 18:00 19:45 20:30 22:00 TO LOCATION ARRIVE LOCATION MU TOOL, STANDBY PU GYRO. MU LUBRICATOR. START INRUN SURVEY SURVEY CONTINUOUS TO 8750' OUTRUN CONTINUOUS 100FPM. RIG DOWN RTN TO ATLAS SUNDAY,05/18/97 07:30 PROCESS SURVEY/CHECK TOOL/FAX RESULTS TO RIG 12:30 RETURN TO MILNE POINT WITH RESULTS. 17:25 TO ANCHORAGE. SPEi BP EXPLORATION MILNE POINT / MPF-05 500292276200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/10/97 -SUN DRILLING SERVICESANcHORAGE ALASKA ~'7 QT~~ PAGE DATE OF SURVEY: 050297 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-70128 KELLY BUSHING ELEV. = 41.30 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. .00 .00 -41.30 114.70 114.70 73.40 174.17 174.17 132.87 264.23 264.23 222.93 354.44 354.44 313.14 0 0 N .00 E .00 0 8 S 88.47 E .13 0 7 N 89.41 E .03 0 9 S 76.87 E .05 0 11 S 87.62 E .05 .00N .00E .00 .00S .15E -.14 .01S .29E -.28 .03S .51E -.48 .07S .77E -.73 445.24 445.24 403.94 536.80 536.80 495.50 627.51 627.51 586.21 719.85 719.85 678.55 811.20 811.19 769.89 0 10 N 69.27 E .08 0 13 N 54.08 E .07 0 14 N 73.99 E .09 0 20 N 88.92 E .14 0 25 S 84.67 E .11 .02S 1.05E -1.01 .13N 1.33E -1.31 .28N 1.64E -1.66 .34N 2.10E -2.11 .31N 2.71E -2.70 900.90 900.89 859.59 991.33 991.32 950.02 1087.11 1087.10 1045.80 1182.74 1182.72 1141.42 1278.60 1278.58 1237.28 0 30 S 77.59 E .10 0 24 S 77.64 E .10 0 20 S 82.03 E .07 0 28 S 72.41 E .16 0 38 S 63.88 E .18 .20N 3.43E -3.36 .04N 4.13E -3.99 .07S 4.75E -4.56 .23S 5.42E -5.16 .59S 6.28E -5.90 1374.05 1374.02 1332.72 1469.63 1469.60 1428.30 1565.34 1565.30 1524.00 1659.74 1659.69 1618.39 1753.84 1753.78 1712.48 0 35 N 71.23 E .49 0 39 S 68.83 E .45 0 40 S 61.29 E .09 0 48 S 59.79 E .14 0 43 S 50.23 E .16 .66S 7.22E -6.78 .70S 8.20E -7.72 1.17S 9.21E -8.57 1.77S 10.27E -9.43 2.48S 11.29E -10.23 1849.44 1849.38 1808.08 1944.96 1944.89 1903.59 2040.69 2040.57 1999.27 2136.19 2135.84 2094.54 2231.75 2230.86 2189.56 0 42 S 41.14 E .12 0 42 S 7.92 W .62 2 36 S 55.62 W 2.29 4 55 S 67.29 W 2.55 7 5 S 72.37 W 2.33 3.31S 12.14E -10.83 4.34S 12.45E -10.85 6.15S 10.58E -8.57 8.95S 5.01E -2.45 12.33S 4.40W 7.52 2325.89 2323.93 2282.63 2421.33 2417.46 2376.16 2516.08 2509.43 2468.13 2611.58 2601.07 2559.77 2707.13 2691.69 2650.39 10 7 S 76.66 W 3.29 12 40 S 77.47 W 2.67 15 3 S 76.67 W 2.53 17 37 S 77.35 W 2.69 19 17 S 78.04 W 1.77 16.00S 18.00W 21.60 20.20S 36.38W 40.44 25.30S 58.51W 63.12 31.32S 84.69W 89.96 37.77S 114.24W 120.17 2801.66 2780.61 2739.31 2897.17 2869.19 2827.89 2992.66 2955.82 2914.52 3088.37 3041.02 2999.72 3183.74 3123.95 3082.65 20 21 S 78.96 W 1.16 23 32 S 77.37 W 3.40 26 12 S 74.47 W 3.07 27 58 S 72.87 W 2.00 31 10 S 73.80 W 3.38 44.15S 145.66W 152.15 51.50S 180.58W 187.77 61.32S 219.51W 227.91 73.60S 261.33W 271.49 87.08S 306.42W 318.54 SPE! -SLrN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPF-05 500292276200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/10/97 DATE OF SURVEY: 050297 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-70128 KELLY BUSHING ELEV. = 41.30 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3279.28 3204.52 3163.22 33 50 S 74.68 W 2.84 101.01S 355.83W 3374.86 3282.87 3241.57 36 0 S 74.45 W 2.26 115.57S 408.56W 3469.72 3358.66 3317.36 37 55 S 74.06 W 2.04 131.06S 463.44W 3565.20 3432.74 3391.44 40 17 S 73.81 W 2.49 147.72S 521.30W 3660.72 3505.34 3464.04 40 46 S 73.09 W .70 165.41S 580.80W 369.88 424.58 481.61 541.81 603.87 3756.10 3576.50 3535.20 42 42 S 73.63 W 2.07 183.59S 641.63W 3851.65 3645.99 3604.69 43 58 S 74.26 W 1.39 201.72S 704.65W 3947.09 3712.53 3671.23 47 35 S 75.07 W 3.85 219.80S 770.61W 4042.14 3776.33 3735.03 48 4 S 75.56 W .63 237.65S 838.76W 4137.49 3839.17 3797.87 49 28 S 76.67 W 1.71 254.85S 908.37W 667.35 732.92 801.31 871.75 943.43 4232.87 3899.47 3858.17 52 5 S 77.60 W 2.86 271.29S 980.41W 4328.69 3956.76 3915.46 54 26 S 77.42 W 2.45 287.90S 1055.37W 4424.55 4010.69 3969.39 57 5 S 77.48 W 2.76 305.12S 1132.72W 4520.37 4060.46 4019.16 60 19 S 77.20 W 3.38 323.07S 1212.59W 4616.15 4107.74 4066.44 60 31 S 77.17 W .21 341.54S 1293.82W 1017.25 1093.93 1173.08 1254.85 1338.06 4711.88 4154.92 4113.62 60 25 S 75.11 W 1.88 361.49S 1374.67W 4807.35 4202.44 4161.14 59 52 S 75.57 W .70 382.45S 1454.78W 4902.99 4249.82 4208.52 60 43 S 72.89 W 2.59 405.03S 1534.70W 4998.69 4297.02 4255.73 60 10 S 71.91 W 1.06 430.19S 1614.05W 5094.24 4344.91 4303.61 59 40 S 71.80 W .52 455.94S 1692.63W 5189.87 4392.11 4350.81 61 9 S 71.59 W 1 56 482.05S 1771.58W 5284.82 4438.27 4396.97 60 40 S 70.92 W .80 508.72S 1850.15W 5380.00 4484.99 4443.69 60 31 S 71.05 W .19 535.73S 1928.55W 5413.00 4501.27 4459.98 60 19 S 71.65 W 1.69 544.91S 1955.74W 5460.00 4524.57 4483.27 60 14 S 71.01 W 1.20 557.98S 1994.42W 1421.31 1504.11 1587.16 1670.34 1752.93 1835.98 1918.82 2001.57 2030.23 2070.98 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 2071.00 FEET AT SOUTH 74 DEG. 22 MIN. WEST AT MD = 5460 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 254.60 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD LAST SURVEY STATION AT 5,460.00' MD SPE f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPF-05 500292276200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/10/97 DATE OF SURVEY: 050297 JOB NUMBER: AK-EI-70128 KELLY BUSHING ELEV. = 41.30 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION .00 .00 -41.30 .00 N .00 E .00 1000.00 999.99 958.69 .03 N 4.19 E .01 2000.00 1999.92 1958.62 5.10 S 12.10 E .08 3000.00 2962.40 2921.10 62.19 S 222.63 W 37.60 4000.00 3748.17 3706.87 229.84 S 808.40 W 251.83 .01 .07 37.51 214.23 5000.00 4297.68 4256.38 430.55 S 1615.13 W 702.32 5460.00 4524.57 4483.27 557.98 S 1994.42 W 935.43 450.50 233.10 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPEi -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPF-05 500292276200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/10/97 DATE OF SURVEY: 050297 JOB NUMBER: AK-EI-70128 KELLY BUSHING ELEV. = 41.30 FT. OPEKATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -41.3 41.30 41.30 .0 141.30 141.30 100.0 241.30 241.30 200.0 341.30 341.30 300.0 .00 N .00 N .01 S .02 S .06 S .00 E .00 E .21 E .45 E .73 E .00 .00 .00 .00 .00 .00 .00 .00 .00 441.30 441.30 400.0 541.30 541.30 500.0 641.30 641.30 600.0 741.30 741.30 700.0 841.31 841.30 800.0 .03 S 1.04 E .00 .00 .14 N 1.34 E .00 .00 .30 N 1.70 E .00 .00 .34 N 2.23 E .00 .00 .29 N 2.94 E .01 .00 941.31 941.30 900.0 1041.31 1041.30 1000.0 1141.32 1141.30 1100.0 1241.32 1241.30 1200.0 1341.33 1341.30 1300.0 .12 N 3.77 E .01 .00 .03 S 4.48 E .01 .00 .13 S 5.09 E .02 .00 .40 S 5.91 E .02 .00 .77 S 6.90 E .03 .01 1441.33 1441.30 1400.0 1541.34 1541.30 1500.0 1641.35 1641.30 1600.0 1741.35 1741.30 1700.0 1841.36 1841.30 1800.0 .58 S 1.04 S 1.64 S 2.38 S 3.24 S . 8. 10. 11. 12. 89 E .03 .01 96 E .04 .01 04 E .05 .01 17 E .05 .01 08 E .06 .01 1941.37 1941.30 1900.0 2041.42 2041.30 2000.0 2141.67 2141.30 2100.0 2242.28 2241.30 2200.0 2343.54 2341.30 2300.0 4.30 S 12.46 E .07 .01 6.17 S 10.55 E .12 .05 9.14 S 4.57 E .37 .25 12.72 S 5.68 W .98 .61 16.71 S 21.02 W 2.24 1.26 2445.76 2441.30 2400.0 2549.16 2541.30 2500.0 2653.80 2641.30 2600.0 2759.73 2741.30 2700.0 2866.87 2841.30 2800.0 21.37 S 41.62 W 4.46 2.23 27.32 S 67.14 W 7.86 3.40 34.13 S 97.17 W 12.50 4.64 41.36 S 131.35 W 18.43 5.93 48.97 S 169.02 W 25.57 7.14 2976.51 2941.30 2900.0 3088.70 3041.30 3000.0 3204.09 3141.30 3100.0 3323.63 3241.30 3200.0 3447.71 3341.30 3300.0 59.47 S 212.70 W 35.21 9.64 73.65 S 261.49 W 47.40 12.19 90.03 S 316.64 W 62.79 15.39 107.56 S 379.72 W 82.33 19.54 127.34 S 450.44 W 106.41 24.08 SPE}. -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPF-05 500292276200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/10/97 DATE OF SURVEY: 050297 JOB NUMBER: AK-EI-70128 KELLY BUSHING ELEV. = 41.30 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3576.43 3441.30 3400.00 149.75 S 528.27 W 3708.35 3541.30 3500.00 174.46 S 610.68 W 3845.15 3641.30 3600.00 200.50 S 700.31 W 3989.78 3741.30 3700.00 227.91 S 801.09 W 4140.77 3841.30 3800.00 255.43 S 910.80 W 135.13 28.71 167.05 31.92 203.85 36.79 248.48 44.63 299.47 50.99 4302.10 3941.30 3900.00 283.19 S 1034.26 W 4482.45 4041.30 4000.00 315.85 S 1180.67 W 4684.29 4141.30 4100.00 355.33 S 1351.48 W 4885.57 4241.30 4200.00 400.56 S 1520.18 W 5087.09 4341.30 4300.00 454.01 S 1686.77 W 360.80 61.33 441.15 80.35 542.99 101.84 644.27 101.28 745.79 101.53 5291.01 4441.30 4400.00 510.48 S 1855.26 W 849.71 5460.00 4524.57 4483.27 557.98 S 1994.42 W 935.43 103.92 85.71 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS SPE~ f-SUN DRILLING SERVICES ANCHOP~AGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPF-05 500292276200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/10/97 DATE OF SURVEY: 050697 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-70132 KELLY BUSHING ELEV. = 41.30 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. .00 .00 -41.30 114.70 114.70 73.40 174.17 174.17 132.87 264.23 264.23 222.93 354.44 354.44 313.14 0 8 7 9 11 N .00 E .00 .00N .00E S 88.47 E .13 .00S .15E N 89.41 E .03 .01S .29E S 76.87 E .05 .03S .51E S 87.62 E .05 .07S .77E .00 -.14 - .28 - .48 -.73 445.24 445.24 403.94 0 536.80 536.80 495.50 0 627.51 627.51 586.21 0 719.85 719.85 678.55 0 811.20 811.19 769.89 0 10 13 14 20 25 N 69.27 E .08 .02S 1.05E N 54.08 E .07 .13N 1.33E N 73.99 E .09 .28N 1.64E N 88.92 E .14 .34N 2.10E S 84.67 E .11 .31N 2.71E -1.01 -1.31 -1.66 -2.11 -2.70 900.90 900.89 859.59 0 991.33 991.32 950.02 0 087.11 1087.10 1045.80 0 182.74 1182.72 1t41.42 0 278.60 1278.58 1237.28 0 30 24 20 28 38 S 77.59 E .10 .20N 3.43E S 77.64 E .10 .04N 4.13E S 82.03 E .07 .07S 4.75E S 72.41 E .16 .23S 5.42E S 63.88 E .18 .59S 6.28E -3.36 -3.99 -4.56 -5.16 -5.90 1374.05 1374.02 1332.72 0 1469.63 1469.60 1428.30 0 1565.34 1565.30 1524.00 0 1659.74 1659.69 1618.39 0 1753.84 1753.78 1712.48 0 35 39 4O 48 43 N 71.23 E .49 .66S 7.22E S 68.83 E .45 .70S 8.20E S 61.29 E .09 1.17S 9.21E S 59.79 E .14 1.77S 10.27E S 50.23 E .16 2.48S 11.29E -6.78 -7.72 -8.57 -9.43 -10.23 1849.44 1849.38 1808.08 0 1944.96 1944.89 1903.59 0 2040.69 2040.57 1999.27 2 2136.19 2135.84 2094.54 4 2231.75 2230.86 2189.56 7 42 42 36 55 5 S 41.14 E .12 3.31S 12.14E S 7.92 W .62 4.34S 12.45E S 55.62 W 2.29 6.15S 10.58E S 67.29 W 2.55 8.95S 5.01E S 72.37 W 2.33 12.33S 4.40W -10.83 -10.85 -8.57 -2.45 7.52 2325.89 2323.93 2282.63 2421.33 2417.46 2376.16 2516.08 2509.43 2468.13 2611.58 2601.07 2559.77 2707.13 2691.69 2650.39 10 12 15 17 19 7 4O 3 37 17 S 76.66 W 3.29 16.00S 18.00W S 77.47 W 2.67 20.20S 36.38W S 76.67 W 2.53 25.30S 58.51W S 77.35 W 2.69 31.32S 84.69W S 78.04 W 1.77 37.77S 114.24W 21.60 40.44 63.12 89.96 120.17 2801.66 2780.61 2739.31 2897.17 2869.19 2827.89 2992.66 2955.82 2914.52 3088.37 3041.02 2999.72 3183.74 3123.95 3082.65 20 23 26 27 31 21 32 12 58 10 S 78.96 W 1.16 44.15S 145.66W S 77.37 W 3.40 51.50S 180.58W S 74.47 W 3.07 61.32S 219.51W S 72.87 W 2.00 73.60S 261.33W S 73.80 W 3.38 87.08S 306.42W 152.15 187.77 227.91 271.49 318.54 ORIGiNAl_ SPE~ f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPF-05 500292276200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/10/97 DATE OF SURVEY: 050697 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-70132 KELLY BUSHING ELEV. = 41.30 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATE DEGREES DG/100 NORTH/SOUTH EAST/WEST S VERT. SECT. 3279.28 3204.52 3163.22 3374.86 3282.87 3241.57 3469.72 3358.66 3317.36 3565.20 3432.74 3391.44 3660.72 3505.34 3464.04 33 50 S 74.68 W 2.84 101.01S 355.83W 36 0 S 74.45 W 2.26 115.57S 408.56W 37 55 S 74.06 W 2.04 131.06S 463.44W 40 17 S 73.81 W 2.49 147.72S 521.30W 40 46 S 73.09 W .70 165.41S 580.80W 369.88 424.58 481.61 541.81 603.87 3756.10 3576.50 3535.20 3851.65 3645.99 3604.69 3947.09 3712.53 3671.23 4042.14 3776.33 3735.03 4137.49 3839.17 3797.87 42 42 S 73.63 W 2.07 183.59S 641.63W 43 58 S 74.26 W 1.39 201.72S 704.65W 47 35 S 75.07 W 3.85 219.80S 770.61W 48 4 S 75.56 W .63 237.65S 838.76W 49 28 S 76.67 W 1.71 254.85S 908.37W 667.35 732.92 801.31 871.75 943.43 4232.87 3899.47 3858.17 4328.69 3956.76 3915.46 4424.55 4010.69 3969.39 4520.37 4060.46 4019.16 4616.15 4107.74 4066.44 52 5 S 77.60 W 2.86 271.29S 980.41W 54 26 S 77.42 W 2.45 287.90S 1055.37W 57 5 S 77.48 W 2.76 305.12S 1132.72W 60 19 S 77.20 W 3.38 323.07S 1212.59W 60 31 S 77.17 W .21 341.54S 1293.82W 1017.25 1093.93 1173.08 1254.85 1338.06 4711.88 4154.92 4113.62 4807.35 4202.44 4161.14 4902.99 4249.82 4208.52 4998.69 4297.02 4255.73 5094.24 4344.91 4303.61 60 25 S 75.11 W 1.88 361.49S 1374.67W 59 52 S 75.57 W .70 382.45S 1454.78W 60 43 S 72.89 W 2.59 405.03S 1534.70W 60 10 S 71.91 W 1.06 430.19S 1614.05W 59 40 S 71.80 W .52 455.94S 1692.63W 1421.31 1504.11 1587.16 1670.34 1752.93 5189.87 4392.11 4350.81 5284.82 4438.27 4396.97 5380.00 4484.99 4443.69 5413.00 4501.27 4459.98 5460.00 4524.57 4483.27 61 9 S 71.59 W 1.56 482.05S 1771.58W 60 40 S 70.92 W .80 508.72S 1850.15W 60 31 S 71.05 W .19 535.73S 1928.55W 60 19 S 71.65 W 1.69 544.91S 1955.74W 60 14 S 71.01 W 1.20 557.98S 1994.42W 1835.98 1918.82 2001.57 2030.23 2070.98 5618.35 4603.93 4562.63 5713.47 4654.23 4612.93 5809.09 4708.34 4667.04 5904.72 4765.03 4723.73 5999.84 4823.83 4782.53 59 36 S 68.88 W 1.23 604.95S 2123.12W 56 31 S 69.34 W 3.26 633.73S 2198.53W 54 31 S 71.21 W 2.64 660.34S 2272.71W 52 44 S 72.43 W 2.13 684.38S 2345.85W 50 53 S 73.83 W 2.27 706.08S 2417.39W 2207.54 2287.88 2366.47 2443.37 2518.09 6094.98 4885.42 4844.12 6190.32 4950.28 4908.98 6284.84 5017.34 4976.04 6379.87 5087.42 5046.13 6474.89 5160.09 5118.79 48 24 S 75.15 W 2.81 725.48S 2487.24W 45 50 S 75.34 W 2.69 743.28S 2554.80W 43 45 S 76.48 W 2.38 759.50S 2619.38W 41 i2 S 76.96 W 2.70 774.24S 2681.83W 39 0 S 77.57 W 2.35 787.74S 2741.52W 2590.59 2660.46 2727.03 2791.15 2852.27 SPE~ -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPF-05 500292276200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/10/97 DATE OF SURVEY: 050697 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-70132 KELLY BUSHING ELEV. = 41.30 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 6570.64 5235.70 5194.40 36 40 S 77.23 W 2.44 800.54S 2798.83W 6666.10 5313.40 5272.10 34 19 S 76.78 W 2.47 813.00S 2852.83W 6759.94 5391.86 5350.56 32 10 S 75.32 W 2.45 825.39S 2902.75W 6853.53 5472.06 5430.76 29 50 S 75.19 W 2.49 837.65S 2949.37W 6946.07 5553.38 5512.08 27 10 S 74.63 W 2.90 849.14S 2992.00W 2910.92 2966.30 3017.72 3065.91 3110.07 7039.22 5637.13 5595.83 24 42 S 73.98 W 2.67 860.15S 3031.22W 7132.69 5722.68 5681.38 22 46 S 75.72 W 2.20 870.01S 3067.52W 7226.57 5810.06 5768.76 20 6 S 74.42 W 2.88 878.82S 3100.67W 7318.57 5897.10 5855.80 17 36 S 73.29 W 2.75 887.07S 3129.24W 7412.17 5986.81 5945.51 15 26 S 74.15 W 2.33 894.55S 3154.79W 3150.80 3188.41 3222.72 3252.45 3279.07 7505.18 6076.92 6035.62 13 9 S 73.34 W 2.46 900.96S 3176.84W 7599.48 6169.08 6127.78 11 16 S 71.21 W 2.06 907.01S 3195.85W 7693.00 6261.09 6219.79 9 11 S 73.04 W 2.24 912.13S 3211.65W 7786.69 6353.80 6312.50 7 19 S 77.75 W 2.13 915.58S 3224.64W 7880.94 6447.47 6406.17 5 11 S 82.28 W 2.31 917.43S 3234.74W 3302.03 3321.96 3338.56 3352.00 3362.23 7975.29 6541.57 6500.27 2 54 S 85.94 W 2.44 918.17S 3241.37W 8069.93 6636.13 6594.83 1 17 N 57.93 W 2.13 917.78S 3244.68W 8163.09 6729.28 6687.98 0 10 N 47.11 E 1.45 917.12S 3245.47W 8255.64 6821.83 6780.53 0 24 N 87.15 E .32 917.01S 3245.05W 8348.96 6915.15 6873.85 0 27 S 87.56 E .07 917.01S 3244.35W 3368.82 3371.90 3372.49 3372.05 3371.38 8442.98 7009.16 6967.86 0 27 S 67.89 E .17 917.17S 3243.62W 8536.05 7102.23 7060.93 0 35 S 19.05 E .49 917.78S 3243.11W 8630.01 7196.18 7154.88 0 49 S 4.40 E .30 918.91S 3242.89W 8713.00 7279.16 7237.86 1 2 S 10.09 W .39 920.24S 3242.98W 8754.46 7320.61 7279.31 1 2 S 9.35 W .00 920.99S 3243.11W 3370.72 3370.38 3370.48 3370.92 3371.24 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3371.34 FEET AT SOUTH 74 DEG. 8 MIN. WEST AT MD = 8754 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 254.60 DEG. TIE-IN SURVEY AT SURFACE 0.00' LAST SURVEY STATION AT 8,754.46' SPEi -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPF-05 500292276200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/10/97 DATE OF SURVEY: 050697 JOB NUMBER: AK-EI-70132 KELLY BUSHING ELEV. = 41.30 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION .00 .00 -41.30 .00 N .00 E .0 1000.00 999.99 958.69 .03 N 4.19 E .0 2000.00 1999.92 1958.62 5.10 S 12.10 E .0 3000.00 2962.40 2921.10 62.19 S 222.63 W 37.6 4000.00 3748.17 3706,87 229.84 S 808.40 W 251.8 .01 .07 37.51 214.23 5000.00 4297.68 4256.38 430.55 S 1615.13 W 702.3 6000.00 4823.93 4782.63 706.12 S 2417.50 W 1176.0 7000.00 5601.50 5560.20 855.63 S 3015.46 W 1398.5 8000.00 6566.24 6524.94 918.26 S 3242.62 W 1433.7 8754.46 7320.61 7279.31 920.99 S 3243.11 W 1433.8 450.50 473.75 222.43 35.25 .09 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPEi -SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE 5 BP EXPLORATION MILNE POINT / MPF-05 500292276200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/10/97 DATE OF SURVEY: 050697 JOB NUMBER: AK-EI-70132 KELLY BUSHING ELEV. = 41.30 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -41.30 41.30 41.30 .00 141.30 141.30 100.00 241.30 241.30 200.00 341.30 341.30 300.00 .00 N .00 E .00 N .00 E .01 S .21 E .02 S .45 E .06 S .73 E .00 .00 .00 .00 .00 .00 .00 .00 .00 441.30 441.30 400.00 541.30 541.30 500.00 641.30 641.30 600.00 741.30 741.30 700.00 841.31 841.30 800.00 .03 S 1.04 .14 N 1.34 .30 N 1.70 .34 N 2.23 .29 N 2.94 .00 .00 .00 .00 .01 .00 .00 .00 .00 .00 941.31 941.30 900.00 1041.31 1041.30 10.00.00 1141.32 1141.30 1100.00 1241.32 1241.30 1200.00 1341.33 1341.30 1300.00 .12 N 3.77 .03 S 4.48 .13 S 5.09 .40 S 5.91 .77 S 6.90 .01 .01 .02 .02 .03 .00 .00 .00 .00 .01 1441.33 1441.30 1400.00 1541.34 1541.30 1500.00 1641.35 1641.30 1600.00 1741.35 1741.30 1700.00 1841.36 1841.30 1800.00 .58 S 7.89 1.04 S 8.96 1.64 S 10.04 2.38 S 11.17 3.24 S 12.08 .03 .04 .05 .05 .06 .01 .01 .01 .01 .01 1941.37 1941.30 1900.00 2041.42 2041.30 2000.00 2141.67 2141.30 2100.00 2242.28 2241.30 2200.00 2343.54 2341.30 2300.00 4.30 S 12.46 6.17 S 10.55 9.14 S 4.57 12.72 S 5.68 16.71 S 21.02 .07 .12 .37 .98 2.24 .01 .05 .25 .61 1.26 2445.76 2441.30 2400.00 2549.16 2541.30 2500.00 2653.80 2641.30 2600.00 2759.73 2741.30 2700.00 2866.87 2841.30 2800.00 21.37 S 41.62 27.32 S 67.14 34.13 S 97.17 41.36 S 131.35 48.97 S 169.02 . 7. 12. 18. 25. 46 86 5O 43 57 2.23 3.40 4.64 5.93 7.14 2976.51 2941.30 2900.00 3088.70 3041.30 3000.00 3204.09 3141.30 3100.00 3323.63 3241.30 3200.00 3447.71 3341.30 3300.00 59.47 S 212.70 73.65 S 261.49 90.03 S 316.64 107.56 S 379.72 127.34 S 450.44 35. 47. 62. 82. 106. 21 40 79 33 41 9.64 12.19 15.39 19.54 24.08 SPE, -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPF-05 500292276200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/10/97 DATE OF SURVEY: 050697 JOB NIZ~BER: AK-EI-70132 KELLY BUSHING ELEV. = 41.30 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 3576.43 3441.30 3400.00 3708.35 3541.30 3500.00 3845.15 3641.30 3600.00 3989.78 3741.30 3700.00 '4140.77 3841.30 3800.00 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 149.75 S 528.27 W 174.46 S 610.68 W 200.50 S 700.31 W 227.91 S 801.09 W 255.43 S 910.80 W MD-TVD VERTICAL DIFFERENCE CORRECTION 135.13 28.71 167.05 31.92 203.85 36.79 248.48 44.63 299.47 50.99 4302 . 10 3941 . 30 3900 . 00 4482.45 4041.30 4000.00 4684 . 29 4141 . 30 4100 . 00 4885 . 57 4241.30 4200 . 00 5087 . 09 4341.30 4300 . 00 283.19 S 1034.26 315.85 S 1180.67 355.33 S 1351.48 400.56 S 1520.18 454.01 S 1686.77 W 360.80 61.33 W 441.15 80.35 W 542.99 101.84 W 644.27 101.28 W 745.79 101.53 5291.01 4441.30 4400.00 5493.70 4541.30 4500.00 5689.74 4641.30 4600.00 5865.52 4741.30 4700.00 6027.30 4841.30 4800.00 510.48 S 1855.26 W 567.50 S 2022.08 W 626.69 S 2179.92 W 674.96 S 2316.11 W 711.91 S 2437.75 W 849.71 103.92 952.40 102.69 1048.44 96.04 1124.22 75.78 1186.00 61.78 6177.37 4941.30 4900.00 6317.76 5041.30 5000.00 6450.71 5141.30 5100.00 6577.62 5241.30 5200.00 6699.89 5341.30 5300.00 740.92 S 2545.78 W 764.74 S 2641.34 W 784.47 S 2726.66 W 801.47 S 2802.89 W 817.36 S 2871.38 W 1236.07 50.07 1276.46 40.38 1309.41 32.95 1336.32 26.91 1358.59 22.26 6818.05 5441.30 5400.00 6932.46 5541.30 5500.00 7043.81 5641.30 5600.00 7152.83 5741.30 5700.00 7259.84 5841.30 5800.00 833.14 S 2932.28 847.49 S 2985.95 860.68 S 3033.06 871.92 S 3074.96 881.90 S 3111.69 1376.75 18.16 1391.16 14.41 1402.51 11.35 1411.53 9.02 1418.54 7.01 7364.91 5941.30 5900.00 7468.59 6041.30 6000.00 7571.16 6141.30 6100.00 7672.95 6241.30 6200.00 7774.09 6341.30 6300.00 891.05 S 3142.54 W 898.57 S 3168.86 W 905.22 S 3190.61 W 911.20 S 3208.58 W 915.24 S 3223.08 W 1423.61 5.06 1427.29 3.69 1429.86 2.56 1431.65 1.79 1432.79 1.14 7874.74 6441.30 6400.00 7975.02 6541.30 6500.00 8075.10 6641.30 6600.00 8175.11 6741.30 6700.00 8275.11 6841.30 6800.00 917.35 S 3234.19 918.17 S 3241.36 917.71 S 3244.78 917.10 S 3245.45 917.01 S 3244.91 W W W W W 1433.44 .66 1433.72 .28 1433.80 .08 1433.81 .01 1433.81 .00 SPEt -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPF-05 500292276200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/10/97 DATE OF SURVEY: 050697 JOB NUMBER: AK-EI-70132 KELLY BUSHING ELEV. = 41.30 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RE CTANGULAR COORDINATE S NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8375.11 6941.30 6900.00 917.02 S 3244.14 W 1433.81 .00 8475.12 7041.30 7000.00 917.27 S 3243.37 W 1433.82 .00 8575.12 7141.30 7100.00 918.16 S 3242.97 W 1433.82 .00 8675.13 7241.30 7200.00 919.58 S 3242.87 W 1433.83 .01 8754.46 7320.62 7279.31 920.99 S 3243.11 W 1433.84 .01 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS SPEA _-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPF-05 500292276200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/13/97 DATE OF SURVEY: 050597 MWD SURVEY JOB NUMBER: AK-MM-70125 KELLY BUSHING ELEV. = 41.30 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. .00 .00 -41.30 112.00 112.00 70.70 208.00 208.00 166.70 298.18 298.18 256.88 389.91 389.91 348.61 N .00 E .00 .00N .00E .00 N .00 E .00 .00N .00E .00 S 28.48 W .04 .03S .02W .02 S 55.33 E .13 .liS .04E -.01 S 55.26 E .00 .21S .18E -.12 479.17 479.17 437.87 569.69 569.69 528.39 661.85 661.85 620.55 752.97 752.97 711.67 844.52 844.52 803.22 7 S 22.20 W .16 .34S .22E -.12 7 N 29.29 E .26 .35S .23E -.13 3 N 72.87 E .10 .25S .32E -.24 11 S 49.91 E .18 .34S .47E -.36 24 S 57.53 E .23 .61S .86E -.66 935.66 935.66 894.36 1026.05 1026.04 984.74 1119.35 1119.34 1078.04 1212.81 1212.80 1171.50 1305.15 1305.14 1263.84 19 10 21 31 37 S 61.04 E .08 .90S 1.35E -1.07 S 57.81 E .17 1.11S 1.70E -1.35 S 46.14 E .20 1.39S 2.04E -1.60 S 57.99 E .20 1.81S 2.61E -2.03 S 50.18 E .14 2.36S 3.35E -2.60 1397.99 1397.97 1356.67 1491.09 1491.07 1449.77 1585.04 1585.01 1543.71 1677.33 1677.29 1635.99 1770.39 1770.35 1729.05 37 28 39 45 40 S 37.64 E .14 3.08S 4.04E -3.08 S 53.87 E .23 3.70S 4.66E -3.51 S 48.68 E .21 4.28S 5.37E -4.04 S 46.19 E .11 5.06S 6.21E -4.65 S 33.75 E .19 5.94S 6.96E -5.13 1863.22 1863.17 1821.87 1957.41 1957.35 1916.05 2051.42 2051.27 2009.97 2145.25 2144.83 2103.53 2238.70 2237.66 2196.36 42 11 12 19 40 S 30.80 E .06 6.88S 7.56E -5.46 S 36.88 W 1.20 8.17S 7.27E -4.84 S 57.94 W 2.28 10.35S 4.45E -1.55 S 66.54 W 2.35 13.48S 1.77W 5.29 S 73.27 W 2.63 17.00S 11.72W 15.82 2333.79 2331.51 2290.21 2428.52 2424.13 2382.83 2522.31 2514.86 2473.56 2614.72 2603.25 2561.95 2708.07 2691.51 2650.21 10 13 15 18 19 46 24 51 0 57 S 76.57 W 3.31 20.89S 26.45W 31.04 S 78.51 W 2.82 25.13S 45.82W 50.85 S 77.47 W 2.62 30.08S 68.98W 74.50 S 78.04 W 2.34 35.78S 95.28W 101.36 S 79.57 W 2.16 41.65S 125.07W 131.64 2801.89 2779.23 2737.93 2894.88 2865.08 2823.78 2988.74 2950.25 2908.95 3082.04 3033.06 2991.76 3175.50 3114.15 3072.85 21 23 26 28 30 33 34 7 43 51 S 79.28 W 1.71 47.76S 157.75W 164.77 S 77.77 W 2.25 54.87S 192.71W 200.36 S 75.28 W 2.94 64.10S 231.04W 239.77 S 74.27 W 2.84 75.40S 272.50W 282.74 S 74.95 W 2.31 87.72S 317.27W 329.17 ORIGINAL SPE~ -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPF-05 500292276200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/13/97 DATE OF SURVEY: 050597 MWD SURVEY JOB NUMBER: AK-MM-70125 KELLY BUSHING ELEV. = 41.30 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COD-RS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3268.93 3193.30 3152.00 33 17 3362.88 3270.86 3229.56 35 22 3454.40 3344.62 3303.32 37 12 3547.89 3418.03 3376.73 39 16 3640.95 3488.87 3447.57 41 33 S 74.91 W 2.61 100.615 365.17W S 75.75 W 2.26 114.025 416.42W S 75.20 W 2.04 127.615 468.85W S 73.61 W 2.45 143.185 524.58W S 74.72 W 2.57 159.635 582.61W 378.78 431.75 485.91 543.76 604.09 3735.62 3558.84 3517.54 43 7 3828.33 3625.66 3584.36 44 38 3921.73 3690.92 3649.62 46 41 4017.30 3755.30 3714.00 48 35 4112.97 3817.79 3776.49 49 49 S 75.14 W 1.67 176.205 644.18W S 74.95 W 1.65 192.795 706.26W S 74.31 W 2.25 210.505 770.66W S 74.69 W 2.02 229.365 838.71W S 76.00 W 1.65 247.685 908.78W 667.84 732.10 798.89 869.50 941.93 4209.14 3878.88 3837.58 51 16 4304.59 3937.06 3895.76 53 35 4399.47 3991.67 3950.37 56 7 4458.72 4024.15 3982.85 57 23 4554.34 4073.54 4032.24 60 24 S 75.90 W 1.51 265.715 980.82W S 76.13 W 2.43 283.995 1054.22W S 75.63 W 2.71 302.925 1129.46W S 75.87 W 2.15 315.125 1177.49W S 76.69 W 3.23 334.525 1257.02W 1016.17 1091.79 1169.35 1218.89 1300.72 4650.15 4120.95 4079.65 60 16 4745.25 4168.43 4127.13 59 49 4840.95 4216.30 ~4175.00 60 9 4936.03 4263.60 4222.30 60 10 5032.30 4311.65 4270.35 59 56 S 76.19 W .47 354.045 1337.95W S 75.23 W 1.00 374.385 1417.80W S 73.71 W 1.42 396.575 1497.63W S 72.80 W .83 420.335 1576.61W S 72.27 W .54 445.375 1656.19W 1383.93 1466.31 1549.17 1631.62 1714.99 5127.26 4358.60 4317.30 60 47 5224.05 4405.73 4364.44 60 55 5318.67 4451.92 4410.63 60 37 5413.64 4498.73 4457.43 60 18 5495.95 4539.74 4498.44 59 55 S 72.37 W .90 470.435 1734.82W S 71.76 W .57 496.465 1815.25W S 71.30 W .53 522.635 1893.58W S 72.37 W 1.04 548.395 1972.09W S 70.96 W 1.56 570.835 2039.83W 1797.46 1881.92 1964.38 2046.91 2118.18 5609.05 4596.77 4555.48 5704.06 4646.93 4605.63 5797.98 4699.81 4658.51 5893.35 4756.25 4714.95 5988.02 4814.74 4773.44 59 30 56 46 54 42 52 43 50 57 S 68.36 W 2.02 604.775 2131.38W S 67.83 W 2.91 634.865 2206.24W S 70.93 W 3.51 662.225 2278.86W S 70.65 W 2.08 687.505 2351.45W S 74.44 W 3.66 709.855 2422.43W 2215.46 2295.62 2372.90 2449.59 2523.96 6082.62 4875.90 4834.60 6178.63 4941.10 4899.80 6275.92 5010.00 4968.70 6371.02 5080.03 5038.73 6463.47 5150.70 5109.40 48 45 43 41 39 29 57 51 16 1 S 76.22 W 2.98 728.155 2492.24W S 75.32 W 2.73 745.465 2560.54W S 76.47 W 2.30 762.215 2627.13W S 77.89 W 2.90 776.505 2689.84W S 79.90 W 2.81 788.005 2748.32W 2596.12 2666.56 2735.21 2799.47 2858.90 SPER -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPF-05 500292276200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/13/97 DATE OF SURVEY: 050597 MWD SURVEY JOB NUMBER: AK-MM-70125 KELLY BUSHING ELEV. = 41.30 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 6559.31 5226.29 5184.99 36 49 6654.74 5303.84 5262.54 34 25 6750.15 5383.52 5342.22 32 17 6840.04 5460.47 5419.17 29 54 6933.79 5542.79 5501.49 27 14 S 78.47 W 2.46 799.03S 2806.16W 2917.60 S 77.10 W 2.66 810.77S 2860.48W 2973.08 S 76.99 W 2.22 822.53S 2911.60W 3025.49 S 75.80 W 2.75 833.43S 2956.73W 3071.89 S 75.39 W 2.86 844.58S 3000.16W 3116.72 7025.12 5624.82 5583.52 24 52 7118.60 5710.27 5668.97 22 57 7211.82 5796.90 5755.60 20 21 7305.41 5885.36 5844.06 17 43 7398.02 5974.08 5932.78 15 32 S 74.57 W 2.62 854.96S 3038.90W 3156.83 S 77.45 W 2.40 864.15S 3075.63W 3194.68 S 75.34 W 2.90 872.21S 3109.07W 3229.06 S 74.62 W 2.82 880.11S 3138.56W 3259.59 S 75.15 W 2.37 887.03S 3164.15W 3286.10 7491.22 6064.33 6023.03 13 17 7584.77 6155.69 6114.39 11 27 7679.62 6248.98 6207.68 9 15 7773.91 6342.27 6300.97 7 22 7869.04 6436.81 6395.51 5 11 S 74.42 W 2.42 893.10S 3186.54W 3309.30 S 71.67 W 2.05 898.92S 3205.72W 3329.33 S 72.59 W 2.34 904.16S 3221.94W 3346.36 S 76.59 W 2.07 907.83S 3235.06W 3359.98 S 81.29 W 2.35 909.90S 3245.26W 3370.37 7963.47 6530.98 6489.68 2 53 8060.86 6628.30 6587.00 1 12 8154.37 6721.80 6680.50 0 15 8247.16 6814.59 6773.29 0 31 8339.90 6907.32 6866.02 0 32 S 86.02 W 2.47 910.71S 3251.87W 3376.96 N 56.93 W 2.12 910.33S 3255.17W 3380.04 S 89.80 E 1.52 909.79S 3255.78W 3380.48 N 87.72 E .28 909.78S 3255.15W 3379.87 S 76.34 E .16 909.87S 3254.30W 3379.08 8432.13 6999.55 6958.25 0 25 8526.02 7093.43 7052.13 0 40 8619.81 7187.21 7145.92 0 49 8713.75 7281.14 7239.84 1 2 8807.05 7374.43 7333.13 1 9 S 70.39 E .13 910.08S 3253.55W 3378.42 S 22.07 E .53 910.71S 3253.02W 3378.06 S 3.70 E .31 911.90S 3252.77W 3378.14 S 3.35 W .25 913.43S 3252.77W 3378.55 S 10.37 W .19 915.20S 3252.99W 3379.23 8834.98 7402.35 7361.05 1 9 S 13.05 W .19 8895.00 7462.36 7421.06 1 9 S 13.05 W .00 915.76S 3253.11W 3379.49 916.94S 3253.38W 3380.07 THE CALCULATION PROCEDURES A_RE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3380.13 FEET AT SOUTH 74 DEG. 15 MIN. WEST AT MD = 8895 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 254.60 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 8,895.00' MD SPER. -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPF-05 500292276200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/13/97 DATE OF SURVEY: 050597 JOB NUMBER: AK-MM-70125 KELLY BUSHING ELEV. = 41.30 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION .00 .00 -41.30 .00 N .00 E .0 1000.00 999.99 958.69 1.06 S 1.63 E .0 2000.00 1999.93 1958.63 8.88 S 6.74 E .0 3000.00 2960.35 2919.05 65.37 S 235.86 W 39.6 4000.00 3743.86 3702.56 225.94 S 826.19 W 256.1 .01 .07 39.58 216.49 5000.00 4295.47 4254.17 436.85 S 1629.56 W 704.5 6000.00 4822.31 4781.01 712.33 S 2431.38 W 1177.6 7000.00 5602.03 5560.73 852.15 S 3028.71 W 1397.9 8000.00 6567.47 6526.17 910.84 S 3253.70 W 1432.5 8895.00 7462.36 7421.06 916.94 S 3253.38 W 1432.6 448.39 473.16 220.28 34.56 .11 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPER -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPF-05 500292276200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/13/97 DATE OF SURVEY: 050597 JOB NUMBER: AK-MM-70125 KELLY BUSHING ELEV. = 41.30 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -41.30 41.30 41.30 .00 141.30 141.30 100.00 241.30 241.30 200.00 341.30 341.30 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .00 N .00 E .00 .00 .05 S .03 W .00 .00 .15 S .11 E .00 .00 441.30 441.30 400.00 541 . 30 541 . 30 500 . O0 641 . 30 641 . 30 600 . O0 741 . 30 741 . 30 700 . O0 841.30 841.30 800.00 .27 S .25 E .00 .00 .40 S .20 E .00 .00 .26 S .30 E .00 .00 .31 S .44 E .00 .00 .59 S .84 E .00 .00 941.30 941.30 900.00 1041.31 1041.30 1000.00 1141.31 1141.30 1100.00 1241.31 1241.30 1200.00 1341.32 1341.30 1300.00 .92 S 1.38 1.13 S 1.74 1.48 S 2.14 1.95 S 2.83 2.61 S 3.65 E .00 .00 E .01 .00 E .01 .00 E .01 .00 E .02 .01 1441.32 1441.30 1400.00 1541.33 1541.30 1500.00 1641.33 1641.30 1600.00 1741.34 1741.30 1700.00 1841.35 1841.30 1800.00 3.44 S 4.33 3.95 S 5.00 4.73 S 5.87 5.66 S 6.77 6.65 S 7.42 E .02 .01 E .03 .00 E .03 .01 E .04 .01 E .05 .01 1941.36 1941.30 1900.00 2041.43 2041.30 2000.00 2141.71 2141.30 2100.00 2242.38 2241.30 2200.00 2343.77 2341.30 2300.00 7.90 S 7.47 10.05 S 4.93 13.34 S 1.47 17.14 S 12.21 21.33 S 28.30 E .06 .01 E .13 .07 W .41 .28 W 1.08 .67 W 2.47 1.39 2446.17 2441.30 2400.00 2549.80 2541.30 2500.00 2654.73 2641.30 2600.00 2761.11 2741.30 2700.00 2868.93 2841.30 2800.00 25.95 S 49.84 31.71 S 76.31 38.34 S 107.38 44.97 S 143.03 52.68 S 182.57 W 4.87 2.41 W 8.50 3.63 W 13.43 4.94 W 19.81 6.38 W 27.63 7.82 2978.78 2941.30 2900.00 3091.44 3041.30 3000.00 3207.13 3141.30 3100.00 3326.62 3241.30 3200.00 3450.23 3341.30 3300.00 63.01 S 226.82 76.63 S 276.84 91.93 S 332.93 108.86 S 396.08 126.97 S 466.41 W 37.48 9.85 W 50.14 12.65 W 65.83 15.69 W 85.32 19.50 W 108.93 23.60 SPEt -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPF-05 500292276200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/13/97 DATE OF SURVEY: 050597 JOB NUMBER: AK-MM-70125 KELLY BUSHING ELEV. = 41.30 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3577.95 3441.30 3400.00 3711.59 3541.30 3500.00 3850.31 3641.30 3600.00 3996.13 3741.30 3700.00 4149.42 3841.30 3800.00 148.55 S 542.83 171.99 S 628.30 196.80 S 721.18 225.17 S 823.39 254.42 S 935.81 W 136.65 27.72 W 170.29 33.65 W 209.01 38.72 W 254.83 45.82 W 308.12 53 . 29 4311.77 3941.30 3900.00 4491.04 4041.30 4000.00 4691.18 4141.30 4100.00 4891.18 4241.30 4200.00 5091.80 4341.30 4300.00 285.38 S 1059.85 321.73 S 1204.07 362.57 S 1372.54 408.87 S 1539.43 461.06 S 1705.33 W 370.47 62.35 W 449.74 79.27 W 549.88 100.13 W 649.88 100.01 W 750.50 100.62 5297.01 4441.30 4400.00 5499.07 4541.30 4500.00 5693.71 4641.30 4600.00 5868.67 4741.30 4700.00 6029.67 4841.30 4800.00 516.57 S 1875.70 571.71 S 2042.38 631.60 S 2198.20 681.00 S 2332.92 718.24 S 2453.40 W 855.71 105.21 W 957.77 102.06 W 1052.42 94.65 W 1127.37 74.96 W 1188.37 61.00 6178.92 4941.30 4900.00 6318.91 5041.30 5000.00 6451.33 5141.30 5100.00 6578.06 5241.30 5200.00 6700.15 5341.30 5300.00 745.51 S 2560.73 768.94 S 2655.81 786.62 S 2740.75 801.28 S 2817.18 816.50 S 2885.49 W 1237.62 49.25 W 1277.61 40.00 W 1310.03 32.41 W 1336.76 26.74 W 1358.85 22.08 6817.93 5441.30 5400.00 6932.10 5541.30 5500.00 7043.28 5641.30 5600.00 7152.18 5741.30 5700.00 7258.98 5841.30 5800.00 830.73 S 2946.04 844.38 S 2999.39 856.99 S 3046.26 867.02 S 3088.13 876.27 S 3124.43 1376.63 17.78 1390.80 14.18 1401.98 11.18 1410.88 8.89 1417.68 6.80 7364.00 5941.30 5900.00 7467.56 6041.30 6000.00 7570.08 6141.30 6100.00 7671.84 6241.30 6200.00 7772.94 6341.30 6300.00 884.69 S 3155.34 891.64 S 3181.30 898.00 S 3202.95 903.79 S 3220.74 907.80 S 3234.94 W W W W W 1422.70 5.02 1426.26 3.56 1428.78 2.53 1430.54 1.75 1431.64 1.10 7873.55 6441.30 6400.00 7973.80 6541.30 6500.00 8073.86 6641.30 6600.00 8173.87 6741.30 6700.00 8273.88 6841.30 6800.00 909.96 S 3245.67 910.75 S 3252.39 910.18 S 3255.40 909.79 S 3255.69 909.77 S 3254.91 W W W W W 1432.25 .62 1432.50 .25 1432.56 .06 1432.57 .01 1432.58 .00 SPER -SUN DRILLING SERVICES ANCHOR3~GE ALASKA PAGE BP EXPLORATION MILNE POINT / MPF-05 500292276200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/13/97 DATE OF SURVEY: 050597 JOB NUMBER: AK-MM-70125 KELLY BUSHING ELEV. = 41.30 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8373.88 6941.30 6900.00 909.94 S 3253.99 W 1432.58 .00 8473.88 7041.30 7000.00 910.19 S 3253.26 W 1432.58 .00 8573.89 7141.30 7100.00 911.25 S 3252.82 W 1432.59 .01 8673.90 7241.30 7200.00 912.71 S 3252.73 W 1432.60 .01 8773.92 7341.30 7300.00 914.54 S 3252.87 W 1432.62 .02 8873.94 7441.30 7400.00 916.52 S 3253.29 W 1432.64 .02 8895.00 7462.36 7421.06 916.94 S 3253.38 W 1432.64 .00 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS emm -sur, Ci !::t I I--I-- I IM G WELL LOG TRANSMITTAL To: State of Alaska July 30, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - MPF-05, AK-MM-70125 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Yn-n Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 0-7'4 2" x 5" MD Resistivity and Gamma Ray Logs: 50-029-22762-00 2" x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22762-00 2"x 5" MD Neutron and Density Logs: 50-029-22762-00 2"x 5" TVD Neutron and Density Logs: 50-029-22762-00 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia dUL ~0 i~gT 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, inc. Company mi:Ill--LING WELL LOG TRANSMITTAL -- To: State of Alaska July 23, 1997 Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - ~MPF-05, AK-MM-70125 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a Signed copy of this transmittal letter to the attention off Yah Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted LIS Tape with verification listing. API#: 50-029-22762-00 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11142 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) 7/11/97 Well Job # Log Description Date BL RF Sepia LIS Tape MPF-05 "~ "'~ J~ OI 97298 GR/CCL PDC 970517 1 MPF-26 '-~ ~,_~'0 97295 GR/CCL PDC 970525 1 ...... PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received by: _~j~~ ~ 6/3O/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie Field: NO. 11118 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape MPU B-14 L.~ ~ £ .... INJECTION PROFILE 970607 I 1 MPU E-07 ~-.~- \ (L .... INJECTION PROFILE 970606 I 1 MPU E-16 ~' INJECTION PROFILE 970605 I 1 MPU F-05 ~-' PERFORATION RECORD 97051 7 I 1 MPU F-05 ~ ..... TEMP & PRESSURE SURVEY 97051 7 I 1 MPU F-05 ~" GPJCCL LOG 970517 1 1 MPU F-26 v' GPJCCL LOG 970525 I 1 ,,, MPU F-26 ~r" STATIC PRESS &TEMP 970527 I 1 MPU F--26 V' PERFORATION RECORD 970527 I 1 MPU F'50 '"' PERFORATION RECORD 970508 I 1 , , MPU F-50 STATIC PRESSURE SURVEY 970509 I 1 MPU F-57 '/'" PERFORATION RECORD 97051 2 I 1 MPU F-62 ~." I.~l,.I (. INJECTION PROFILE 970608 1 1 MPU F-65 .~' PERFORATION RECORD 970511 I 1 MPH -07 ~..- GR/CCL RECORD 970424 I 1 MPH -07 '~' GPJCCL RECORD 970427 1 I ~.~' 7.- 0'39 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3~3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received ~~.~~ TONY KNOWLE$, GOVEFtNOFt ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 24, 1997 Tim Schofield Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPF-05 BP Exploration (Alaska) Inc. Permit No 97-74 Sur. Loc.: 1735'NSL, 2784'WEL, Sec. 06, T13N, R10E. UM Btmhole Loc: 834'NSL. 893'WEL, Sec. 01. T13N, R09E. UM Dear Mr. Schofield: Encloscd is the approvcd application for permit to drill the above rcfcrcnccd well. Thc permit to drill docs not exempt you from obtaining additional permits required bv laxv from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Conu'nission may witness the test. Notice mav be given by contacting the Commission petroleum field inspector on the North Slope Chairm~,,,, ~ BY ORDE~ISSION dlffcnclosurcs cc; I)cpartmcnt of Fish & (}amc. I Iabitat Section w/o cncl. Department ot' l';nvinommcnt Conscn'ation w,o encl. f- . APR 21 '97 03:04PM B.P.. EXPLORATION¢~_ MILHE POINT rnn l~u, · i m, aaavdmvr OF m sorm c D/VISION OF OIL AND. TONY KNDWL~..q, November. 18, 1996'.' BP Expl~r'ati. on~ (At.mi<a) Inc, 900 East Benson Blvd. P.O. Box, 196612 Anchorage, Alaska 99519-6612 Attn: Howard ~. M~y~on Miln¢ Point Asset Manager ~ubje, c.r: Applications for Expansion of MilndPoint Unit and Dcf~-raI of Milae Poim Unit Contraction ADL 3550~3 Expansion Area Dcm' On Suly.$,' 1996, iBP Exploration (Alaska) Inc. (BPX') and OXY' USA Inc., (OX'Y) applied to expand rile Milne Po.mt Unit (MPU)-to includc'th~ easrr, m pordon of ADL35502,3. In a scparato applicatioa filed contemporaneously with the ~xpansion application, BPX and OXY requested that the date for contracting tho eastern portion of A,DL 355023 imm th, MPU b~ extended from December 31., 1996 to De, celrtb~ 31, 1997. As part'of im application for .defewal of e, ontta~tion of the e, ast~m portion of ADL 355023 from the MPU and as justification for the cl,fcnal request, BPX and OXY ptovid~ - a plm of dovelolament, for thc expansion acreage. The Division of Oil and C,~ approves the exparu;ion of th~ lvlPU to iacludo thc ~aste, m portion or ADL 3~$023. The division further approves the deferral of contraction of these lan& from the MPU until Decemb~ 31. 1997. Th, ~ff~tive dat~ ofboda dccisicm, s is No¥,mbcr I2, 1996. A Decision and Findings .o~ tll¢ Commissioner explaining tke basis for these approvals will be issued by Dec~rnber ~ 1.1996. .~, 2 't ]997 .~.3~ ;~:inle.,1 on recycleo O~per b Ir C.,. D. Mx. t{oward.L Maysoa November 18, 1996 Page 2 .~ ~.qT-03/O3 A person adversely affected by this dee, ir, ion may appeal this ~on, in accordanc,~ with 11 AAC 02, to ]'ohn Shively, Commisslonor, .l~p~t of N'atural Resources, 3601 C Street, Suit~ i210, Anchorage, AIask~' 99503-5921. Any appeal must b~ reoeiv~ at th~ above address, or received by be.~g P~xed to .t-9074624871, withil1.30 c~lendar days after the date of"delivery" of th/s dee/sion, as defined in 11 AAC 02.040. A copy of I 1 AAC 02 may be obtained fi'om any ggional informat, ioa office of the Department of Natural Re. sources, · $iac~gly, Kenneth A. Boyd Dixector $coR ~L Kerr- ARCO Todd. Kratz - Chevron ~. P. Holhcr- Mob/l C. hristophcr A. Cos~cllo=- Unocal NLM12~0P ~ DEPARTMENT OF NATURAL RESOURCES CASE FILE DETAIL PAGE: FILE: ADL 355023 ACTION CODE: SEE NON-DISPLAY? N SEE ERRORS? N CUSTOMER-ID: ~?i!~%90107377 BP'EXPLoP~ATiON (ALASKA) INC CASE TYPE: 784 OIL & GAS LEASE COMP CUST UNIT: 780 OIL Ai~D GAS FILE LOCATION FROM: DOG DIV OIL Ai~D GAS TO: DOG DIV OIL AND GAS CASE STATUS: 20 ACTIVE STATUS DATE: 06 16 1983 TOTAL ACRES: 5,175.000 DATE INITIATED: 03 24 1983 OFFICE OF PRIMARY RESPONSIBILITY: DOG DIV OIL /LND GAS ~AST TR3LNSACTIOND'ATE~ll"'"25'~99~6~ SALE AREA BS BEAUFORT SEA LAST TRANSACTION: AA-NRB ASSIGNMENT APPROVED M: U T: 013N R: 009E S: 1 TOTAL ACRES: 640 M: U T: 013N R: 009E S: 2 TOTAL ACRES: 640 M: U T: 013N R: 009E S: 3 TOTAL ACRES: 640 M: U T: 013N R: 009E S: 4 TOTAL ACRES: 640 M: U T: 013N R: 009E S: 8 TOTAL ACRES: 55 M: U T: 013N R: 009E S: 9 TOTAL ACRES: 640 M: U T: 013N R: 009E S: 10 TOTAL ACRES: 640 M: U T: 013N R: 009E S: 11 TOTAL ACRES: 640 M: U T: 013N R: 009E S: 12 TOTAL ACRES: 640 TRANSACTION: INITIATE INITIATE CASE TP_Ai~SACTION DATE: 03 24 1983 TIME: 113430 SUBSYSTEM-ID: CAS INPUT DATE: 09 19 1986 USER: MJSTAPLE TERMINAL: NAW0 ONLINE STATUS DATE 03 24 1983 LOCATION FROM DOG DIV OIL AND GAS LOCATION TO DOG DIV OIL Ai~D GAS CASE STATUS 10 INITIAL LEGAL DESC OFFICE PRI RESP DOG DIV OIL Ai~D GAS SPECIAL CODE BS BEAUFORT SEA CUSTOMER N-gMBER 000002453 SALE 39 UNIT CODE 780 OIL AND GAS RELATIONSHIP CODE 21 DISPOSAL NAME TOTAL ACRES 5175 M: U T: 013N R: 009E S: 4 ACRES: 640 M: U T: 013N R: 009E S: 3 ACRES: 640 M: U T: 013N R: 009E S: 2 ACRES: 640 M: U T: 013N R: 009E S: 1 ACRES: 640 M: U T: 013N R: 009E S: 8 ACRES: 55 M: U T: 013N R: 009E S: 9 ACRES: 640 M: U T: 013N R: 009E S: 10 ACRES: 640 M: U T: 013N R: 009E S: 11 ACRES: 640 M: U T: 013N R: 009E S: 12 ACRES: 640 TtLANSACTION: TD TRACT DEFINED TR_Ai~SACTION DATE: 03 24 1983 TIME: 113447 SUBSYSTEM-ID: CAS INPUT DATE: 09 19 1986 USER: MJSTAPLE TERMINAL: NAW0 SALE DATE 05 17 1983 STATUS (11) 11 BID TYPE 2 SALE NLIMBER 39 TRACT N-UMBER 39-23 FORM NUMBER 17 CONDITIONAL Y/N N PRIMARY TERM 10 04/21/1997 08:55:09 1 DNR 10-1113 5/83 NPS ONLINE TRACT DEFINED FIXED ROYALTY & NPS NLM12~0P FILE: ADL ACTION CODE: DEPARTMENT OF NATURAL RESOURCES 04/21/1997 08:55:09 CASE FILE DETAIL PAGE: 2 355023 SEE NON-DISPLAY? N SEE ERRORS? N TRAi~SACTION: ADDTEXT CHANGE LEGAL TEXT TRANSACTION DATE: 03 24 1983 TIME: 113719 INPUT DATE: 09 19 1986 USER: MJSTAPLE TR3LNSACTION: BR BID RECEIVED TRAlqSACTION DATE:'~ 0.51,.-17.1R83,~ TIME: 113848 INPUT DATE: 09 19 1986 STATUS (12) BID TYPE TOTAL BONUS BID DEPOSIT AMOUNT ROYALTY SHARE % NET PROFIT SHARE % ~i~EXT: .ARCO.ALAS!~KA',[ iNC'~ ;i~!"9..9~'~ TRANSACTION: NLD NOTIFICATION LESSEE DESIGNATED TRANSACTION DATE: 05 17 1983 INPUT DATE: 09 19 1986 NEW REA (20) OLD REL CODE NOTIFICATION CID NUMBER OLD CID # (SALE NO) TEXT: ATTN: JAMES M. POSEY SUBSYSTEM-ID: CAS TERMINAL: NAW0 ONLINE SUBSYSTEM-ID: CAS USER: MJSTAPLE TERMINAL: NAW0 12 BID RECEIVED 2 FIXED ROYALTY & NPS 2365233.75 473046.75 12.5 30 TIME: 113930 USER: MJSTAPLE 20 21 106346 2453 ONLINE TR3~NSACTION: LI LEASE ISSUED TPJ~NSACTION DATE: 06 16 1983 TIME: 114020 INPUT DATE: 09 19 1986 USER: MJSTAPLE EFFECTIVE DATE 06 01 1983 EXPIP~ATN DATE 05 31 1993 STATUS (20) 20 SUBSYSTEM-ID: CAS TERMINAL: NAW0 ACTIVE TRAi~SACTION: LA LEASE AWARDED TRANSACTION DATE: 05 27 1983 TIME: 113947 SUBSYSTEM-ID: CAS INPUT DATE: 09 19 1986 USER: MJSTAPLE TERMINAL: NAW0 STATUS (13) 13 LEASE AWARDED ARCO ALASKA INC SUBSYSTEM-ID: CAS TERMINAL: NAX8 SALE 39 SUBSYSTEM-ID: CAS TERMINAL: NAX8 TRANSACTION: ION INITIAL OWNER TRANSACTION DATE: 05 17 1983 TIME: 144805 INPUT DATE: 02 09 1987 USER: TJRUPERT SEGMENT CODE 1 CID NUMBER 000002453 WORKING INTEREST % 0.0 ROYALTY INTEREST % 12.5 ONLINE ONLINE ONLINE ONLINE TR3~NSACTION: ION INITIAL OWNER TP~ANSACTION DATE: 05 17 1983 TIME: 144805 INPUT DATE: 02 09 1987 USER: TJRUPERT SEGMENT CODE 1 CID NUMBER 000106346 WORKING INTEREST % 100 ROYALTY INTEREST % 87.5 SUBSYSTEM-ID: CAS TERMINAL: NAW0 ONLINE NOTIFICATION LESSEE DISPOSAL NAME ARCO ALASKA INC SALE 39 NLM12~0P '~ DEPARTMENT OF NATUR3tL RESOURCES CASE FILE DETAIL FILE: ADL 355023 ACTION CODE: SEE NON-DISPLAY? N SEE ERRORS? N TRANSACTION: COMMENTS COMMENTS TRANSACTION DATE: 07 17 1984 TIME: 114042 SUBSYSTEM-ID: CAS INPUT DATE: 09 19 1986 USER: MJSTAPLE TERMINAL: NAW0 ONLINE TEXT: THE AAINUAL LOCAL HIRE REPORT IS SUSPENDED. TRANSACTION: UNIT '.~..UNITIZED TRANSACTION DATE: 12 05.1.~.~.~i TIME: 114115 SUBSYSTEM-ID: CAS ~ INPUT DATE: 09'I9' 1986 USER: MJSTAPLE TERMINAL: NAW0 ONLINE EFFECTIVE DATE 06 01 1985 UNIT CODE KU 'i,~. KUPARUK RIVER TOTAL ACRES 5175 UNIT ACRES 5175 TRANSACTION: CHNGTEXT CPIANGE LEGAL TEXT TRANSACTION DATE: 12 05 1985 TIME: 114325 SUBSYSTEM-ID: CAS INPUT DATE: 09 19 1986 USER: MJSTAPLE TERMINAL: NAW0 ONLINE ,TRANSACTION: PAE ~iP~Ti~I.PATiNG AREA. ESTABLISHED.i} ~I'~TRANSAdTioN DATE: 12' 05 1.985~ TIME: 114403 SUBSYSTEM-ID: CAS INPUT DATE: 09 19 1986 USER: MJSTAPLE TERMINAL: NAW0 ONLINE EFFECTIVE DATE 06 01 1985 UNIT CODE KU "':'i~KuPARUK RIVER~ TOTAL ACRES 51.75 UNITIZED ACRES 5175 PARTICIPATING ACRES 2080 TRANSACTION: AMD AMENDED DECISION TPJkNSACTION DATE: 06 11 1987 TIME: 144353 SUBSYSTEM-ID: CAS INPUT DATE: 01 06 1992 USER: NORCRBU TERMINAL: NAZB ONLINE ORIG DECIS DATE 12 05 1985 TEXT: LEGAL DESCRIPTION AMENDED TO INCLUDE LAND WITHIN SECTION 8 IN THE KPA, MAKING THE NEW TOTAL ACREAGE = 2135 ACRES TP_ANSACTION: COMMENTS COMMENTS TRANSACTION DATE: 09 12 1990 TIME: 091204 SUBSYSTEM-ID: CAS INPUT DATE: 10 10 1990 USER: NORCKPO TERMINAL: NAW1 ONLINE TEXT: ARCO ROYALTY SETTLEMENT FILE IN AABA FORMULA FOR ROYALTY VALUATION REVISED TR3tNSACTION: PAifN1 PARTICIPATING AREA EXPANDED TPJINSACTION DATE: 12 13 1991 INPUT DATE: 01 06 1992 EFFECTIVE DATE UNIT CODE 1 TOTAL LEASE ACRES UNITIZED ACRES 1 PARTICIPATING ACRES 1 TIME: 142959 USER: NORCRBU 12 01 1990 KU 5175 5175 2935 SUBSYSTEM-ID: CAS TEXT: FOURTH EXPAi~SION OF THE KUPARUK PA TR3kNSACTION: CHNGTEXT CHANGE LEGAL TEXT TRANSACTION DATE: 12 13 1991 TIME: 143527 INPUT DATE: 01 06 1992 USER: NORCRBU TERMINAL: NAZB KUPARUK RIVER SUBSYSTEM-ID: CAS TERMINAL: NAZB 04/21/1997 08:55:09 PAGE: 3 ONLINE ONLINE NLM1Z20P ~ FILE: ADL ACTION CODE: DEPARTMENT OF NATURAL RESOURCES 04/21/1997 08:55:09 CASE FILE DETAIL PAGE: 4 355023 SEE NON-DISPLAY? N SEE ERRORS? N TRANSACTION: NLC .~OTIFIcAT~ON.',~E~SEE_i,[~~:~ ~'~RANSACT~ON DATE:. 11 13 1996'~ TIME: 083117 SUBSYSTEM-ID: CAS INPUT DATE:~ll' 26 'i~996 USER: NORCJST TERMINAL: X2CS ONLINE NEW NL (20) 20 NOTIFICATION LESSEE OLD NL (20) 20 NOTIFICATION LESSEE NEW NOTIF . . .......... :.,,,~,~:~,~,,,:~.,~,,~,~ ,BP: EXPLORATION.,(ALAS~ OLD NOTIF LESSEE'CiD~' 106346 ARCO ALASKA, INC. TR3~NSACTION: ION INITIAL OWNER TRANSACTION DATE: 11 13 1996 TIME: 093941 INPUT DATE: 11 26 1996 USER: NORCJST SEGMENT CODE 2 CID NUMBER 000106346 WORKING INTEREST % 100 ROYALTY INTEREST % 87.5 SUBSYSTEM-ID: CAS TERMINAL: X2CS ARCO ALASKA, INC. ONLINE TRANSACTION: ION INITIAL OWNER TRkNSACTION DATE: 11 13 1996 TIME: 093941 INPUT DATE: 11 26 1996 USER: NORCJST SEGMENT CODE 2 CID NUMBER 000002453 WORKING INTEREST % 0.0 ROYALTY INTEREST % 12.5 SUBSYSTEM-ID: CAS TERMINAL: X2CS SALE 39 ONLINE TRANSACTION: ION INITIAL OWNER TR/LNSACTION DATE: 11 13 1996 TIME: 094738 INPUT DATE: 11 26 1996 USER: NORCJST SEGMENT CODE A CID NI3MBER 000106346 WORKING INTEREST % 100 ROYALTY INTEREST % 87.5 SUBSYSTEM-ID: CAS TERMINAL: X2CS ONLINE ARCO ALASKA, INC. TRANSACTION: ION INITIAL OWNER TRANSACTION DATE: 11 13 1996 TIME: 094738 INPUT DATE: 11 26 1996 USER: NORCJST SEGMENT CODE A CID NUMBER 000002453 WORKING INTEREST % 0.0 ROYALTY INTEREST % 12.5 SUBSYSTEM-ID: CAS TERMINAL: X2CS SALE 39 ONLINE TRANSACTION: CHNGTEXT CH3LNGE LEGAL TEXT TRA/qSACTION DATE: 11 13 1996 TIME: 102449 INPUT DATE: 11 26 1996 USER: NORCJST SUBSYSTEM-ID: CAS TERMINAL: X2CS ONLINE TP3LNSACTION: CHNGTEXT CHANGE LEGAL TEXT TR/LNSACTION DATE: 11 13 1996 TIME: 102638 INPUT DATE: 11 26 1996 USER: NORCJST SUBSYSTEM-ID: CAS TERMINAL: X2CS ONLINE TRAlqSACTION: AA-NRB ASSIGNMENT APPROVEb]~ TRANSACTION DATE: 11 25 1996 TIME: 100527 INPUT DATE: 11 26 1996 USER: NORCJST ~EFFECTIVE DATE 11 13 1996.~ SEGMENT CODE 1 SUBSYSTEM-ID: CAS TERMINAL: X2CS ONLINE NLM1220P '~ DEPARTMENT OF NATURAL RESOURCES CASE FILE DETAIL FILE: ADL 355023 ACTION CODE: SEE NON-DISPLAY? N ASSIGNOR'S CID 000106346, .ASSIGNEE'S CID. 000107377 WORKING ~fNTER % ASSIGNED ' ~ 26,81 ~ ROYALTY INTER % ~S~'i~N~'b '~RAi~SACTION: AAfNRB 'ASSIGNMENTAPPROVED. TPuANSACTION DATE: 11 25 1996 TIME': 100527 SUBSYSTEM-ID: CAS INPUT DATE: 11 26 1996 USER: NORCJST TERMINAL: X2CS EFFECTIVE DATE 11 13 1996 SEGMENT CODE 1 ASSIGNOR'S CID 000106346 ASSIGNEE!S .CID ~. ..000029137. WORKING INTER % ASSIGNED ~, ROYALTYINTER % ASSIGNED 56.3.325..~ ~TRANSACTION:.~NRB ~G~ENT'APPROVE~ -' TRANSACT !0~ ~k~'~' ~' ~"~!":2~'~?i'!':!~!~i'[9~6' TIME :~"i'~ 527 'SUB SYSTEM- I Di~.,i~ ~ INPUT DATE: 11 26 1996 USER: NORCJST ~TERMINAL: X2CS EFFECTIVE DATE 11 13 1996 SEGMENT CODE 1 ASSIGNOR'S CID 000106346 ~,~ASSIGNEE~S CID 000106425 ,~WORKING INTER % ASSIGNED'" ~' ,','8.'81:,' :'~ROYALTY'INTER'% ASSIGNED , TRANSACTION: AA-NRB ASSIGNMENT APPROVED TR2ANSACTION DATE: 11 25 1996 INPUT DATE: 11 26 1996 EFFECTIVE DATE SEGMENT CODE ASSIGNOR'S CID ASSIGNEE'S CID WORKING INTER % ASSIGNED ROYALTY INTER % ASSIGNED TRA/~SACTION: AA-NRB ASSIGNMENT APPROVED TR/LNSACTION DATE: 11 25 1996 INPUT DATE: 11 26 1996 EFFECTIVE DATE SEGMENT CODE ASSIGNOR'S CID ASSIGNEE'S CID WORKING INTER % ASSIGNED ROYALTY INTER % ASSIGNED 04/21/1997 08:55:09 PAGE: 5 ONLINE SEE ERRORS? N ARCO ALASKA, INC. BPEXPLORATION (ALAS' , TRA~NSACTION: A_A-NRB ASSIGNMENT APPROVED TRILNSACTION DATE: 11 25 1996 TIME: 100808 INPUT DATE: 11 26 1996 USER: NORCJST EFFECTIVE DATE 11 13 1996 SEGMENT CODE A ASSIGNOR'S CID 000106346 ASSIGNEE'S CID 000106425 WORKING INTER % ASSIGNED 8.81 TIME: 100808 USER: NORCJST 11 13 1996 A 000106346 000029137 64.38 48.285 ONLINE ONLINE ARCO ALASICA, INC. BP EXPLORATION (ALAS SUBSYSTEM-ID: CAS TERMINAL: X2CS ONLINE ARCO ALASKA, INC. BP EXPLORATION & OIL SUBSYSTEM-ID: CAS TERMINAL: X2CS ONLINE ARCO ALASKA, INC. OXY USA INC. TIME: 100808 SUBSYSTEM-ID: CAS USER: NORCJST TERMINAL: X2CS 11 13 1996 A 000106346 000107377 26.81 20.1075 ARCO ALASRA, INC. oXy USA~.~¢~ ARCO ALASRA, INC. ..BP EXPLORATION & 0Ih NLMi~20P ~- FILE: APL ACTION CODE: DEPARTMENT OF NATURAL RESOURCES 04/21/1997 08:55:09 CASE FILE DETAIL PAGE: 6 355023 SEE NON-DISPLAY? N SEE ERRORS? N ROYALTY INTER % ASSIGNED 6.6075 ***** LEGAL DESCRIPTION ***** 03-24-1983 ***SALE LEGAL DESCRIPTION*** TRACT 39-23 T. 13 N., R. 9 E., UMIAT MERIDIAN, ALASKA SECTION 1, SECTION 2, SECTION 3, SECTION 4, SECTION 8, SECTION 9, SECTION 10, SECTION 11, SECTION 12, PROTRACTED, ALL, PROTRACTED, ALL, PROTRACTED, ALL, WITHIN SECTION 8 SECTION 8, 55.00 PROTRACTED, ALL, PROTRACTED, ALL, PROTRACTED, ALL, 640.00 ACRES; PROTRACTED, ALL, 640.00 ACRES; 640.00 ACRES; 640.00 ACRES; EXCLUDING ALL TIDE AND SUBMERGED LANDS AND THAT PORTION OF USS 4275 WITHIN ACRES; 640.00 ACRES; 640.00 ACRES; PROTP,_ACTED, ALL, 640.00 ACRES; PROTRACTED, ALL, 640.00 ACRES. THIS TR3tCT CONTAINS 5175.00 ACRES MORE OR LESS. 12-05-1985 ***LEASE PARTICIPATING AREA LEGAL DESCRIPTION*** KUPARUK PARTICIPATING AREA T. 13 N., R. 9 E., UMIAT MERIDIAN, ALASKA SECTION 3, SW1/4, 160.00 ACRES; SECTION 4, ALL, 640.00 ACRES; SECTION 9, ALL, 640.00 ACRES; SECTION 10, ALL, 640 ACRES. THIS TRACT CONTAINS 2080.00 ACRES MORE OR LESS. 12-13-91 ***KUPARUK PA EXPANDED*** KUPA_RUK RIVER 1/NIT, PORTION OF TRACT 122 WITHIN THE KPA T.13N.,R.9E., UM SECTION 3: ALL; SECTION 4: ALL; SECTION 8: ALL, EXCLUDING TIDE ialXlD SUBMERGED LANDS AND USS 4275; SECTION 9: ALL; SECTION 10: ALL; SECTION 11: SW1/4, NWl/4. THIS TRACT CONTAINS 2935 ACRES, MORE OR LESS. 11/13/96 ** ASSIGNMENT LEGAL DESCRIPTION *** SEGMENT 1 NLMi~20P ,~ FILE: ADL ACTION CODE: DEPARTMENT OF NATURAL RESOURCES 04/21/1997 08:55:09 CASE FILE DETAIL PAGE: 7 355023 SEE NON-DISPLAY? N SEE ERRORS? N T. 13 N., R. 9 E., UMIAT MERIDID/q, ALASKA SECTION 1, PROTRACTED, ALL, 640.00 ~.ACRES~ SECTION 2, PROTRACTED, Nl'/2, ~S~1/4, 480 ACRES SECTION 11, PROTRACTED, NE1/4, 160 ACRES SECTION 12, PROTRACTED, Ann, 640.00 ACRES. SEGMENT 1 CONTAINS 1,920~ACRES MORE OR LESS FROM THE SURFACE TOA ~DEPTH OF.6881 PotNTi'tINiT~. SEGMENT A SEGMENT A IS THE SAME LEGAL DESCRIPTION AS SEGMENT 1. IT PERTAINS TO LAND BELOW A DEPTH OF 6,881 FEET AND CONTAINS 1,920 ACRES MORE OR LESS AND IS WITHIN THE MILNE POINT UNIT. SEGMENT 2 SECTION 2, PROTRACTED, SW1/4, 160 ACRES SECTION 3, PROTRACTED, ALL, 640.00 ACRES; SECTION 4, PROTRACTED, ALL, 640.00 ACRES; SECTION 8, PROTPJICTED, ALL, EXCLUDING ALL TIDE AND SUBMERGED LANDS WITHIN SECTION 8 AND THAT PORTION OF USS 4275 WITHIN SECTION 8, 55.00 ACRES; SECTION 9, PROTRACTED, ALL, 640.00 ACRES; SECTION 10, PROTRACTED, ALL, 640.00 ACRES; SECTION 11, PROTRACTED, S1/2, NWl/4 480 ACRES SEGMENT 2 CONTAINS 3,255 ACRES MORE OR LESS AND IS WITHIN THE KUPARUK RIVER UNIT. ************************* END OF CASE DETAIL PRINT ************************ STATE OF ALASKA . . · · -~ ALASKA AND GAS CONSERVATION COk .SSlON PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 41.8' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 355023 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1735' NSL, 2784' WEL, SEC. 06, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 834' NSL, 893' WEL, SEC. 01, T13N, R09E, UM MPF-05 At total depth 9. Approximate spud date Amount $200,000.00 834' NSL, 893' WEL, SEC. 01, T13N, R09E, UM 04/25/97 . 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025509, 893'I No Close Approach 5120 8946' MD / 7472' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 2000' Maximum Hole Anqle 60.60° Maximum surface 3158 psig, At total depth (TVD) 7030 / 3509 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 1250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 BTC 5368' 31' 31' 5399' 4475' 1723 sx PF 'E', 767 sx 'G' 8-1/2" 7" 26# L-80 BTC-Mod 8916' 30' 30' 8946' 7472' __.25 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate :~ ~ Production R ~,~__~ ~ Liner ORIGINAL Perforation depth: measured ~aSkS. 0[[ ~ GaS 00tiS, true vertical 'J~Oh0f~0a~' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: James Robertson, 564-5159 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true qnd correct ~ the best of my knowledge Signed ~ .~ Iu_*~J / Tim $(;hgfi¢¢ ._ ~ Title Senior Drilling Engineer Date ~ Commission Use Only t / Permit Number I APl Number I ¢/~P~/~ I See cover letter ¢/~"' 77 50- 0~--¢-'~----.~--~'.~_._ forother requirements Conditions of Approval: Samples Required [] Yes.~' No Mud Lo~ Required [] Yes~ No2~' Hydrogen Sulfide Measures ~Yes [] No Directional Survey Required ,,~ Yes [] No [] [] [] [] [] / , equ,redwor ,, essure or, o, Approved By Other: 0rlglnal SigRfdLI ~, Commissioner the commission Date Form 10-401 Rev. 12-01-85 D~vid W. Johnston Submi ~licate James E. Robertson 564-5159 Shared Services Drilling Contact: I Well Name: IMP F-05 ] Well Plan Summary IType of Well (producer or injector): KUPARUK PRODUCER Surface Location: 1735 NSL 2784 WEL Sec 06 T13N R10E UM., AK Target Location: 834 NSL 893 WEL Sec 01 T13N R09E UM., AK Bottom Hole Location: 834 NSL 893 WEL Sec 01 T13N R09E UM., AK I AFE Number: 1337071 Estimated Start Date: I 25APR97 I I Rig: I Nabors22-E / Operating days to complete: I 11 IMD: 18,946' I I TVD: 17,472' bkb I IKBE: I41.8' IWell Design: IMilne Point Ultra Slimhole Longstring 9-5/8", 40# Surface X 7", 26# Longstring Formation Markers: Formation Tops MD TVD (bkb) base permafrost 1,791.------ 1,791 NA 4000 3755 Top of Schrader Bluff Sands (8.3 ppg) Seabee Shale 4316 3941 Base of Schrader Bluff Sands (8.3 ppg) HRZ 8063 6589 High Resistivity Zone MK-19 8188 6714 Top Kuparuk 8343 6869 Kuparuk Cap Rock Target Sand -Target 8545 7071 Target Sand (9.6 ppg) Total Depth 8946 7472 Casing/Tul ing Program: Hole §ize Csg~ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MDrrVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9-5/8" 40# L-80 btm 5368 31/31 5399/4475 8-1/2" 7" 26# L-80 btm- 8916 30/30 8946/7472 mod Internal yield pressure of the 7" 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at +7030 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3509 psi (9.6 ppg EMW) is 3158 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: Surface MWD Directional surface to TD. LWD Gamma Ray surface to TD Cased Hole Logs: Intermediate N/A Final MWD Directional and LWD Triple Combo CDR/CDN (GR/RES/Dens/Neu). N/A Mudloggers are NOT required for this well. Mud Program: I Special design considerations I None-SPUD MUD Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 50 15 8 10 9 8 to to to to to to to 9.4 150 35 15 30 10 15 Intermediate Mud Properties: N/A I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 35 6 3 7 8.5 6-12 to to to to to to to 10.0 50 20 10 20 9.5 4-6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum ~fehtm~l-surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: I KOP: 12000' I Maximum Hole Angle: Close Approach Well: 60.60 NONE Disposal: Cuffings Handling: Cuttings and drilling waste fluids should be hauled to the ball ' I_..~C-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. , 2. 3. 4. 5. . . 11. 12. 13. 14. 15. MP F-05 Proposed Summary of Operations Drill and Set 20" Conductor. Weld a starting head on conductor. Prepare location for rig move. MIRU Nabors 22E drilling rig. NU and function test 20" diverter. Build Spud Mud. Drill a 12-1/4" surface hole as per directional plan. Run Directional MWD and LWD GR from surface to TD. Run and cement 9-5/8" casing. ND 20" diverter. NU and test 13-5/8" BOP. MU a PDC bit on a motor, with Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). RIH, Drill out Float Equipment and 20' of new formation. Perform LEAKOFF TEST. If LOT EMW is less than 12.5 ppg contact appropriate superintendent. Drill 8.5" hole to TD as per directional plan. Run and Cement 7", 26#, L-80, Buttress-Modified casing. Displace cement with completion fluid and enough diesel to cover from the base of permafrost to surface. Test casing to 3500 psig for 30 min. ND BOPE, NU and Test Tree. RDMO Nabors 22E drilling rig to drill next well. MIRU completion rig. NU & Test BOPE to 5000 psig. Complete well with 2-7/8" tubing. Install Surface Lines and Wellhouse and turn well over to production. DRILLING HAZARDS AND RISKS: See the updated Milne Point F-Pad Data Sheet prepared by Pete Van Dusen for information on F pad and review recent wells drilled on F Pad. Most of the trouble time on recent wells has been due to equipment mechanical problems with the surface equipment, rather than formation drilling problems. The MPU PE group MAY be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. Close Approach: There are no close approaches associated with the drilling of MP F-05. Lost Circulation: There has not been any appreciable amount of lost circulation on any of the F Pad wellls to date. Stuck Pipe Potential: Well MPF-53 was stuck coming out on the short trip at surface casing point. Proir to this incident there was only minor indications that the gravel and coal were present. It appears that we dragged the gravel up into the bottom of the curve and reduced our ability to move up or down. Then we lost the ability to circulate when the hole collapsed. If significant gravels are encountered stop and raise funnel viscosity to 150 cp viscosity immediately. Formation Pressure: The expected pore pressure for this well is 9.6 ppg EMW (3,509 psi @ 7,030' TVD). There has been no injection in this region therefore the reservoir pressure should not exceed this estimate and may in fact be somewhat depleted. MP F-05 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 9-5/8" CIRC. TEMP 60 deg F at 2840' TVDSS. SPACER: 75 bbls spacer weighted to mudweight in the hole. STAGE1 LEAD: TYPE 'E' PERMAFROST ADDITIVES: WEIGHT: APPROX #SACKS: Retarder + CELLO-FLAKES (1/4 lb/sack) 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk 858 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANUULAR VOLUME FROM TOP OF TAIL TO STAGE COLLAR @ 2000' MD (200' TVD BELOW BASE OF PERMAFROST) +30% EXCESS. STAGE1 TAIL CEMENT TYPE: PREMIUM 'G' ADDITIVES: WEIGHT: APPROX #SACKS: FLUID LOSS: 0.2% CFR-3 + 0.20% HALAD-344 + CELLO-FLAKES 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk 767 THICKENING TIME: Greater than 4 hrs at 50° F. 100-150 cc FREE WATER: 0 TAIL CEMENT FROM TD TO 100 FEET TVD ABOVE TOP of Schrader Bluff + 30% EXCESS + 80'md 9-5/8", 40# capacity for float joints. STAGE2 LEAD: TYPE 'E' PERMAFROST ADDITIVES: WEIGHT: APPROX #SACKS: Retarder 12.0 ppg 865 SACKS YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. ANUULAR VOLUME FROM STAGE COLLAR AT 2000' MD TO SURFACE+ 200% EXCESS. WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED ONLY WITH APPROVEL OF APPROPRIATE SUPERINTENDENT IF THERE ARE NO CEMENT RETURNS TO SURFACE OR THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.0 ppg APPROX NO SACKS: 150 YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on bottom 15 joints of casing (15 required). 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Perform lab tests on mixed cementJspacedmud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 - 15 bpm. Mix slurry on the fly -- batch mixing is not necessary. MP F-05 Well 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON SINGLE STAGE CEMENT JOB ACROSS THE KUPARUK INTERVAL: CIRC. TEMP: SPACER: 140° F BHST 170° F at 7040' TVDSS. 20 bbls fresh water 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: WEIGHT: 15.8ppg APPRO× # SACKS: FLUID LOSS: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk 225 SACKS THICKENING TIME: 3 1/2- 4 1/2 hrs @ 140° F < 50cc/30 min @ 140° FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: , 7" x 8-1/4" Straight Blade Rigid Centralizers. Two per joint on the bottom 20 joints of 7" casing (38). This will cover ___300' above the KUPARUK Sand. Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing shoe. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: . Single stage cement job is calculated to cover 1000 FT MD above the Kuparuk 'C' Sand with 30% excess. Ap~-10-97 12:00P Anadrill DPC 907 344 2160 P.08 I i SHARED SERVICES'DRILLING i a~ A , I , · VERTICAL SECTION VIEW Section at; 254..60 TVB Scale · ! inch = ~000 feet i 0 I Oep Scale.' i inch = lO00 feet · ,. · Drawn ..... · 09 Apr ~997 , ~nadr~ ]] Schlumberger 0 B . ii Marker Identification MD BKB SECTN INCLN ., A) KB 0 0 0 0.00 . B) KOP/BUILD 2.5/100 2000 2000 -0 0.00 i i C) END 2.5/,00 BUILD 4424 3997 ,167 60.60 ...... D) 9-5/B" CASING POINT 5399 4475 2016 60.60 0 ..... i E) DROP ~.5/100 5639 4593 2225 60.60 F) END 2.5/100 DROP 8063 6590 3392 0.00 , G) TARGET 8545 7072 3392 0.00 D ; H) 7' CASING POINT 8946 7473 3392 O.OO · %T ' ~D~ ....... ' j ] '~r - ~- ~-~' - - ' ................... --. ,I .o~....:~.. ' ---~AP! RpVE Af~ADRIL1 AKF ' '"' ), 'e~r ~ -~- ~,~--,,-, - - ,~ ~,,,' ...'%"" , , A>.R ]-,'i ) )iNITIAL/~,x~ ~../ '- ·\ · ::: . ,::,---::--::: · --:l)~ .... ' ' .... ~ ' .......... ~ ..... ;;_.;. ._.;... ~;,;.'-bC~q . ;':~.~.~-'~..-', ? . ... ..;.................... .._B)_~ ..-- .............. i .............. I : · : . 0 500 lO00 i500 2000. 2500 . 3000 3500 4000 4500 5000 5500 6000 6500 'SectiOn De ~re I~na~ln~ll Irlq7 WPFr)~PJ ~1 Ar~ ~l-J7 PW PI SHARED SERV '" E'S BRILLTN6 Marker Identi f icat ion MD N/S E/ii A) KB 0 0 N 0 E- B) KOP/BUILD 2.5/~00 2000 0 N 0 E C) END 2.5/100 BUILD 4424 3~0 S 1~25 D) 9-5/8' CASING POINT 53gg 536 S 1944 E) DROP 2.5/100 5639 59t S 2145 F) END 2:5/100 DROP 8063 901 S 3270 il G) TARGET 8545 90~ S 3270 N H) 7" CASING POINT 6946 90~ S 3270 I) TO 8946 90i S 3270 ANADRILL AKA-DPC APPROVED APR ]. (; 1997 !NITIAL'~¢4 ...... ~ ii AnadrJ]] Schlumberger PF-05 (P4) PLAN VIEW CLOSURE · 3392 feet at Azimuth 254.60 DECLINIIION' +2B.042 SCALE. · ! inch: 500 feet DRAWN. · 09 Apr 1997 4250 4000 3750 3500 3250 3000 2750 2500 2250 2000 1750 ~500 1250 1000 750 500 250 0 250 <- WEST' EAST -> [c}97 I~F05~4 3.0C 249 1314 PI ....... v WELL PERMIT CHECKLISToo.~=Y Fi~.LD ~ Poo~, S~_~/~ INIT CLASS PROGRAM: expr] dev~redrlr~ servr~ wellbore segD ann disp para reqD ?.~ :.~ ~,N~T# //,~ ~" O./OFF SHO~ ~0 ~ ADMINISTRATION 1. Permit fee attached ................... 2. Lease number appropriate ................ 3. Unique well name and number ............... 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary. 6. Well located proper distance from other wells ...... 7. Sufficient acreage available in drilling unit ...... 8. If deviated, is wellbore plat included ......... 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ....... ENGINEERING REMARKS 14. Conductor string provided ................ Y N 15. Surface casing protects all known USDWs ........ N 16. CMT vol adequate to circulate on conductor & surf csg. N CMT vol adequate to tie-in long string to surf csg . . . Y 17. 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............ 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate.~ N BOPEs adequate ............. ~,, ...... ~ N 25. 26. BOPE press rating adequate; test to >~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N / 31. Data presented on potential overpressure zones ..... Y y /~ , ~ 32. Seismic analysis of shallow gas zones .......... ~/N ~· · ~ 33. Seabed condition survey (if off-shore) ........ ~ N 34. Contact name/phone for weekly progress reports . . . / Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: JDH ~-~' mcm Comments/Instructions: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER . ****************************** . ............................ * ....... SCHLUMBERGER ....... . ............................ ****************************** RECEIVED ~IUL 1 ~ 1997 COMPANY NAIVE : BP EXPLORATION (ALASKA) WELL NAME : MP F-05 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22762-00 REFERENCE NO : 97298 Date__ LIS T~pe Verification Listing Schlumberger Alaska Computing Center Il-JUL-1997 11:40 PAGE: **** REEL HEADER **** SERVICE NA~E : EDIT DATE : 97/07/11 ORIGIN · FLIC REEL NAME : 97298 CONTINUATION # : PREVIOUS REEL : CO~ENT · BP EXPLORATION, MILNE POINT, MP F-05, API #50-029-22762-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE · 97/07/11 ORIGIN · FLIC TAPE NAME : 97298 CONTINUATION # : 1 PREVIOUS TAPE : COB~ENT : BP EXPLORATION, MILNE POINT, MP F-05, API #50-029-22762-00 TAPE HEADER MILNE POINT CASED HOLE WIRELINE LOGS WELL NAME: MP F- 05 API NUMBER: 500292276200 OPERATOR: BP EXPLORATION (ALASKA) LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: il-JUL-97 JOB NUMBER: 97298 LOGGING ENGINEER: J. MAJCHER OPERATOR WITNESS: J. FOX SURFACE LOCATION SECTION: 6 TOWNSHIP: 13N RANGE: 10E FNL: FSL: 1735 FEL: 2783 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 41.80 DERRICK FLOOR: GROUND LEVEL: 12.30 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 7. 000 26. O0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS T~pe Verification Listing Schlumberger Alaska Computing Center Il-JUL-1997 11:40 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NtC4BER : DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH REMARKS THIS TAPE CONTAINS THE LDWG EDIT FOR BP EXPLORATION WELL MPF-O$. THIS LOG IS THE PRIMARY DEPTH CONTROL FOR THE WELL. WELL LOGGED WITH MAGNETICALLY MARKED LINE. FILE CONTAINS ONLY THE GRCH/CCL/TENS CURVES. THERE IS ONLY AN CLIPPED (EDITED) PASS AND A RAW PASS. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/07/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE H~ER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~IARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8803.0 5341.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: NONE PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH ....... LIS T~pe Verification Listing Schlumberger Alaska Computing Center il-JUL-1997 11:40 PAGE: REM~%RKS: THIS IS THE PRIMARY DEPTH CONTROL LOG. SHIFTING WAS PERFORMED. $ LIS FORMAT DATA NO DEPTH ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 36 66 1 0 66 0 ** SET TYPE - CHAN ** NAIVE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 557843 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH GR GAPI 557843 O0 000 O0 0 1 1 1 4 68 0000000000 TENS GR LB 557843 O0 000 O0 0 1 1 1 4 68 0000000000 CCL GR V 557843 O0 000 O0 0 1 1 1 4 68 0000000000 * * DA TA * * DEPT. 8803.000 GRCH. GR 90.411 TENS.GR 2508.000 CCL.GR DEPT. 5341.000 GRCH. GR 36.838 TENS.GR 1597.000 CCL.GR 0.005 -999.250 ** END OF DATA ** LIS T~pe Verification Listing Schlumberger Alaska Computing Center il-JUL-1997 11:40 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/07/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/07/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFiBER 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SOT~4ARY VENDOR TOOL CODE START DEPTH GRCH 8807.0 $ LOG HEADER DATA STOP DEPTH .......... 5341.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GRCH GAMMA RAY TCC TELEMETRY CARTRIDGE GRCH G~ RAY GRCH GA14MA RAY $ 17-MAY-97 8C0-609 1249 17-MAY-97 8797.0 8789.0 5341.0 8784.0 YES TOOL NUMBER TCC-B SGT-L BNS- CCS LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUL-1997 11:40 PAGE: BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 0.0 8880.0 BOREHOLE CONDITIONS FLUID TYPE .. FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : SEAWATER/DIESEL NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELIIFE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 F~L~ COL~IT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEJL~ COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): REMARKS: LOG IS MEASURED FROM ORIGINAL KB ELEVATION (41.3') TOOL ZEROED (29.5 FT) AT GROUND LEVEL. PRIMARY DEPTH CONTROL IS MAGNETICALLY MARKED LINE. SHORT JOINTS LOCATED AT 8300 FT. CREW: T. FORMAN, R. LISTER $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 LIS T~pe Verification Listing Schlumberger Alaska Computing Center il-JUL-1997 11:40 PAGE: 6 TYPE REPR CODE VALUE 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 557843 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH PDC GAPI 557843 O0 000 O0 0 2 1 1 4 68 0000000000 TENS PDC LB 557843 O0 000 O0 0 2 1 1 4 68 0000000000 CCL PDC V 557843 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA DEPT. 8803 . 000 GRCH. PDC 90. 411 TENS. PDC 2508. 000 CCL. PDC 0.005 ** END OF DATA ** **** FILE TRAILER **** FILE NAME ~ EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE ~ 97/07/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE LIs T~pe Verification Listing Schlumberger Alaska Computing Center il-JUL-1997 11:40 PAGE: **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/07/11 ORIGIN : FLIC TAPE NAME : 97298 CONTINUATION # : 1 PREVIOUS TAPE : COf~4~2~T : BP EXPLORATION, MILNE POINT, MP F-OS, API #50-029-22762-00 **** REEL TRAILER **** SERVICE NA~E : EDIT DATE : 97/07/11 ORIGIN : FLIC REEL NAME : 97298 CONTINUATION # : PREVIOUS REEL : COI~4ENT : BP EXPLORATION, MILNE POINT, MP F-05, API #50-029-22762-00 Sperry-Sun Drilling Services LIS Scan Utility Wed Jul 16 12:38:53 1997 Reel Header Service name ............. LISTPE Date ..................... 97/07/16 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 97/07/16 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Services Technical Services Physical EOF Comment Record TAPE HEADER MILNE POINT UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MM-70125 B. ZIEMKE T. ANGLAN M C OF LM D Date ~ / '" ¢ 3 ~ O MPF-05 500292276200 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 16-JUL-97 MWD RUN 2 AK-MM-70125 B. ZIEMKE C. DIXON 6 13N 10E 1735 2784 .00 29.00 12.30 OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT SIZE (IN) SIZE (IN) DEPTH (FT) 20.000 112.0 12.250 9.625 5570.0 8.500 8895.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ANNULAR HYDRAULICS ARE CALCULATED USING THE POWER LAW MODEL. 3. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 4. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO DENSITY (SLD). 5. THE STABILIZED LITHO DENSITY (SLD) TOOL WAS NOT FUNCTIONAL DURING MWD RUN 2 AND NO DATA WAS ACQUIRED. 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8895'MD, 7462'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED G~ RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SANDSTONE MATRIX-FIXED HOLE SIZE). SNNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. ~ SNFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. ENVIRONMENTAL PARAMETERS USED IN PROCESSING NUCLEAR/NEUTRON LOG DATA: HOLE SIZE = MUD FILTRATE SALINITY = MUD WEIGHT = FORMATION WATER SALINITY = FLUID DENSITY = MATRIX DENSITY = LITHOLOGY = $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/07/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 1000 PPM 8.3 - 9.9 PPG 14545 PPM 1.0 G/CC 2.65 G/CC SANDSTONE Con~ment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE START DEPTH RPD 94.5 RPM 94.5 RPS 94.5 RPX 94.5 GR 94.5 FET 107.0 ROP 108.5 FCNT 5473.5 NCNT 5473.5 NPHI 5473.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 94 5 5418 5 5424 0 5424 5 5524 0 5566 0 5568 0 5588.5 5672.5 5697.5 5704.5 5950.0 6364.0 6382.0 6695.5 6701 5~ 6792 0 6879 5 7064 0 7066 0 7113 5 7150 0 7179 0 7237 0 7238.5 7241.5 7243.5 7258 7261 7274 7339 7343 7344 7345 7351 7507 .5 0 5 5 0 0 5 5 5 GR 100 5426 5431 5432 5530 5571 5574 5593 5674 5692 5699 5950 6367 6389 6691 6697 6787 6885 7058 7058 7107 7144 7173 7234 7236 7237 7237 7251 7253 7268 7344 7345 7347 7349 7355 7509 .0 .0 .0 .0 .0 .5 .0 .5 .5 .0 .0 .5 .0 .0 .0 .5 .0 .0 .0 5 0 0 0 0 0 0 5 5 .5 0 5 5 0 0 5 5 STOP DEPTH 8818.5 8818.5 8818.5 8818.5 8838.0 8818.5 8904.5 8792.0 8792.0 8792.0 EQUIVALENT UNSHIFTED DEPTH 7510.5 7512.5 7578.5 7583 5 7591 0 7595 5 7619 0 7626 0 7677 0 7678 5 7680 0 7792 0 7881.5 7885.5 8059.0 8060.5 8067.5 8069.0 8078.5 8090.0 8091.5 8109.5 8119.5 8137 0 8139 5 8148 0 8152 5 8155 5 8159 0 8162 0 8195 0 8198 5 8216 5 8222 0 8227 5 8236 5 8241 0 8244 5 8246 0 8248 5 8262 5 8264.0 8294.0 8305.0 8306.5 8312.0 8315 0 8332 0 8334 5 8340 0 8387 5 8389 0 8390.5 8394 0 8397 5 8412 0 8429 0 8431 0 8454 5 8456 0 7512 0 7514 5 7573 5 7579 0 7585 0 7590 0 7611 0 7616 5 7670.0 7670 5 7673 0 7787 5 7875 5 7879 0 8050 5 8051 5 8060.5 8061.5 8074.5 8084.0 8085.5 8100.5 8115.0 8134.0 8136.0 8143.5 8147.5 8151.5 8155.5 8157.5 8191.0 8194.0 8213.0 8220.0 8224.0 8232.5 8238.5 8241.5 8242.0 8243.5 8258.5 8259.5 8288.0 8301.0 8302.5 8307.5 8309.5 8329.0 8333.5 8336.5 8383.0 8384.5 8386.5 8390.5 8392.5 8408.0 8424.5 8426.0 8450.5 8452.5 8457 5 8461 0 8463 0 8469 5 8476 0 8482 0 8486.0 8489 0 8495 8515 8527 8557 8562 8904 MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: 8453.5 8456 5 8458 5 8463 0 8471 0 8476 5 8480 5 8484 0 8491.0 8511.0 8521.5 8551.0 8553.0 8895.0 BIT RUN NO MERGE TOP MERGE BASE 1 114.0 5586.0 2 5586.0 8895.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD AAPI 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD P.U. 4 1 68 NCNT MWD CNTS 4 1 68 FCNT MWD CNTS 4 1 68 Code. Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 Name Min Max DEPT 94.5 8904.5 ROP 9.7416 2286.91 GR 10.8235 173.95 RPX 0.1749 102.065 RPS 0.1196 2000 RPM 0.1112 2000 Mean Nsam 4499.5 17621 226.868 17593 69.6609 17488 5.4592 17449 7.4391 17449 10.7088 17449 First Reading 94 5 108 5 94 5 94 5 94 5 94 5 Last Reading 8904.5 8904.5 8838 8818.5 8818.5 8818.5 RPD 0.05 2000 16.2797 17449 FET 0.098 57.3408 1.22204 17424 NPHI 22.1085 81.7622 42.5467 6638 NCNT 2032 3480 2677.51 6638 FCNT 402 1033 636.166 6638 94.5 107 5473.5 5473.5 5473.5 8818.5 8818.5 8792 8792 8792 First Reading For Entire File .......... 94.5 Last Reading For Entire File ........... 8904.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/07/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/07/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 100 0 5520.0 RPM 100 0 5520.0 RPS 100 0 5520.0 RPX 100 0 5520.0 GR 100 0 5510.0 FET 112 5 5520.0 ROP 114.0 5586.0 $ LOG HEADER DATA DATE LOGGED: 01-MAY-97 SOFTWARE SURFACE SOFTWARE VERSION: 4.96 DOWNHOLE SOFTWARE VERSION: 5.46 DATA TYPE (MEMORY OR REAL-TIME}: MEMORY TD DRILLER (FT): 5586.0 TOP LOG INTERVAL (FT): 114.0 BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHM/~) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 5586.0 .0 60.9 TOOL NUMBER P0683CGR8 P0683CGR8 12.250 12.3 SPUD 9.10 65.0 9.5 1000 9.8 1.050 .910 .788 1.575 32.8 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 AAPI 4 1 68 4 2 RPX MWD 1 OHMM 4 1 68 8 3 RP S MWD 1 OHMM 4 1 68 12 4 RPM MWD 1 OHMM 4 1 68 16 5 RPD MWD 1 OHMM 4 1 68 20 6 ROP I~D 1 FT/H 4 1 68 24 7 FET MWD 1 HOUR 4 1 68 28 Name Min Max DEPT 100 5586 GR 10.8235 113.15 RPX 0.1749 31.2717 RPS 0.1378 98.3526 RPM 0.1498 2000 RPD 0.0936 2000 ROP 12.5778 2286.91 FET 0.098 6.2307 Mean Nsam 2843 10973 56.5721 10821 7.09272 10841 10.1027 10841 15.5407 10841 15.2426 10841 256.57 10945 0.645863 10816 First Reading 100 100 100 100 100 100 114 112.5 Last Reading 5586 5510 5520 5520 5520 5520 5586 5520 First Reading For Entire File .......... 100 Last Reading For Entire File ........... 5586 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/07/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/07/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FCNT 5480.5 8782.5 NCNT 5480.5 8782.5 NPHI 5480.5 8782.5 FET 5515.5 8809.0 RPD 5515.5 8809.0 RPM 5515.5 8809.0 RPS 5515.5 8809.0 RPX 5515.5 8809.0 GR 5522.5 ROP 5586.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAlVfMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON $ BOREHOLE AdqD CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8828.5 8895.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S): MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin 05-MAY-97 4.96 5.46 MEMORY 8895.0 5586.0 8895.0 .3 59.5 TOOL NUMBER P0732CRDGP6 P0732CRDGP6 P0732CRDGP6 8.500 8.5 LSND 9.80 50.0 9.0 1000 3.6 1.750 1.056 1.310 2. 625 61.1 Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 GR MWD 2 AAPI 4 1 RPX MWD 2 OH]VIM 4 1 RPS MWD 2 OHMM 4 1 RPM MWD 2 OHMM 4 1 RPD MWD 2 OHMM 4 1 NPHI MWD 2 P.U. 4 1 ROP NfWD 2 FT/H 4 1 FET MWD 2 HOUR 4 1 FCNT MWD 2 CNTS 4 1 NCNT MWD 2 CNTS 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 68 32 9 68 36 10 68 40 11 Name Min Max Mean Nsam DEPT 5480.5 8895 7187.75 6830 GR 25.8019 173.95 91.0041 6613 RPX 0.4292 102.065 2.73086 6588 RPS 0.1196 2000 3.03513 6588 RPM 0.1112 68.6696 2.75849 6588 RPD 0.05 2000 18.6179 6588 NPHI 22.1085 81.7622 42.5833 6605 ROP 9.7416 2032.03 177.919 6618 FET 0.3984 57.3408 2.23695 6588 FCNT 402 1033 635.979 6605 NCNT 2032 3480 2676.77 6605 First Reading 5480 5 5522 5 5515 5 5515 5 5515 5 5515 5 5480 5 5586 5 5515 5 5480.5 5480.5 Last Reading 8895 8828.5 8809 8809 8809 8809 8782.5 8895 8809 8782.5 8782.5 First Reading For Entire File .......... 5480.5 Last Reading For Entire File ........... 8895 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/07/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/07/16 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/07/16 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File